IR 05000335/1989006
| ML17223A148 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 05/05/1989 |
| From: | Kahle J, Stoddart P NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| To: | |
| Shared Package | |
| ML17223A147 | List: |
| References | |
| 50-335-89-06, 50-335-89-6, 50-389-89-06, 50-389-89-6, NUDOCS 8905250124 | |
| Download: ML17223A148 (19) | |
Text
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UNITED STATES NUCLEAR REGULATORY COMMISSION
REGION II
101 MARIETTASTREET, N.W.
ATLANTA,GEORGIA 30323
<<"lAY O 8 ~yg Report Nos.:, 50-335'/89-06 and 50-. 389/89-06 Licensee:
Florida Power and Light Company 9250 West Flagler Street Miami, FL 33102 Docket Nos.:
50-335 and 50-389
"Facility Name:
St.
Lucie 1 and
License Nos.:
DPR-67 and NPF-16 Inspection Conduced~ April 3-7, 1989
./
Inspector:
(
, ~ C:d.m(
P.
G.
toddart
gi,.
W ~l'V DHe Signed Accompanying Personnel:
D.
Seymour Approved by:-~- <<.'1=1<.i
,.
<<>> (C. fi t
<
J.
B. Kahle, Chief R Eliological Effluents and Chemistry
. mergency Preparedness and Radiation Protection Branch Division of Radiation Safety and Safeguards Date Signed SUMMARY Scope This routine, unannounced inspection was conducted in the areas of radioactive waste systems, water chemistry, radiological confirmatory measurements, radiological effluent monitoring',
and radiological environmental monitoring
.
Results Since calendar years 1985-1986, the licensee had reduced plant liquid radio-active effluents for 1987 and 1988 by a factor of ten and had reduced Unit
gaseous releases by a factor of 36 over 1985 releases.
Liquid releases had been reduced by applying more intensive ion exchange techniques, while gaseous releases were reduced through fuel reconstitution and fuel re-design.
Unit 2 gaseous releases remained at about the 1985-1986 level for both 1987 and 1988 but measures taken during the current refueling of Unit 2 were expected to have an impact on reducing Unit 2 gaseous releases.
The 1988 Semi-Annual Effluent Release Reports were reviewed and found to be adequate.
Reviews of radioactive effluent instrumentation, post accident sampling systems, air cleaning systems, the plant meteorological equipment upgrade program and training showed all programs to be adequate.
8905250i24 890508 PDF'DCICK 05000335
The chemistry and radiochemistry programs were considered to be licensee strengths, as were the. quality assurance a'nd quality control programs which contributed substantially to the performance of the chemistry'roup.
The water chemi stry control programs enabled
'the plant to meet or exceed SGOG/EPRI guidance.
The chemistry department had taken a number of innovative approaches to the improvement of pl'ant water chemistry which appeared to have resulted in decreases in piping corrosion, decreases in worker radiation dose during plant outages and decreases in plant radioactive effluents.
No violations or deviations were identifie REPORT DETAILS Persons Contacted'icensee Employees
~A. Bailey, Quality Assurance Supervisor J. Basinger, Senior Quality Assurance Analyst
- K. Beichel, Secondary Chemistry Supervisor
'RE Cox, Acting Chemistry Supervisor D. Faulkner, Primary Chemistry and Effluent Monitor Supervisor R. Frechette, Chemistry Supervisor C. Leppla, Instrumentation and Controls Supervisor M. Serruto, Staff Chemist
- T. Ware, Chemistry Training Coordinator Other licensee employees contacted during this inspection included engineers, operators, technicians, and administrative personnel.
NRC Resident Inspectors S. Elrod, SRI M. Scott, RI
- Attended exit interview Quality Assurance and Quality Control (84750)
The inspector reviewed six Quality Assurance (QA) audits which had been performed either wholly or in part in areas within the scope of this inspection.
All audits appeared to be comprehensive and covered their subject areas in adequate detail.
While a
number of audit findings were identified, only one of these was of concern within the scope of this inspection (Audit Report QSL-OPS-88-6-28, covering the period September 19, 1988, through January 9,
1989).
The finding was of an administrative nature, being concerned with the procurement of a technical assistance contract on a "non-safety-related" purchase order form rather than on a "safety-related" purchase order form.
A second item, not listed as a
new finding, pointed out that the Post Accident Sampling System (PASS), provision for sampling and analyzing hydrogen in primary coolants liquid samples had been out of service since August 1986.
This was listed previously in a 1986 audit (QSL-OPS-86-476)
and was still open; for this reason, the matter was not listed as a
new finding (See also Paragraph 6,
Post Accident Sampling System, in this inspection report).
The audit staff appeared to be competent in the subject areas reviewed.
It was noted that in one example, where the audit staff recognized a
shortcoming, a contractor auditor was brought in for technical assistance..
This action was considered appropriate.
No violations or deviations were identified.
Plant Water Chemistry and Chemistry Controls (84750)
The inspector discussed plant water chemistry and the water chemistry control program with licensee representatives, reviewed plant water chemi stry and water chemi stry control program records and procedures, and visited the water chemistry l.aboratories and the sampling and monitoring area.
In Inspection Report ( IR)
Nos.
50-335/87-24 and 50-389/87-23, the inspector noted that a total of 1,571 tubes in the Unit 1 main condenser and 24 tubes in the Unit 2 main condenser had been plugged on the basis of eddy-current testing indication of severe hydriding (greater than or equal to 50 percent through-wall).
The inspector was informed that since 1987, re-examination of the eddy-current tests had led to removal of approximately 900 of the tube plugs (out of 1,571)
in the Unit
condenser.
Since the 900 plugs were removed, only one small leak was identified and the leaking tube was re-plugged.
During the ongoing outage of Unit 2, three Unit 2 condenser tubes were pulled and the resultant holes plugged; two of,the tubes were removed due to identified leaks and one was pulled on the basis of eddy-current testing results.
Damage to condenser tubes and service water heat exchangers had earlier been reported as being due to fouling with the shells of clams or other micro-organisms growi ng inside the tubes.
Tests utilizing screening devices to prevent the entry of shells with maximum dimensions approximating the internal diameter of the tubes appeared to show that related tube damage was the result of scouring or abrasion of the tube walls as relatively large shells or shell fragments were forced at high speed through the tubes by system flow rather than by growth within the tubes.
All tubes were provided with the protective screens; screens were designed with multiple small holes with an effective open area larger than the tube cross-section area so that partial blockage by debri s would not cause flow restrictions or an increase in pressure drop across the screens.
The licensee had previously reported (IR Nos.
50-335/87-24, 50-389/87-23)
difficulty in maintaining the level of dissolved oxygen (D.O.) below the steam generator owners group (SGOG)
and Electric Power Research Institute (EPRI) guidelines of 10ppb.
Air inleakage to the condensers of both units had been reduced to an indicated 2 to 2',
scfm but extensive testing utilizing a
sensitive sulfur hexafluoride test procedure could not identify further points of air inleakage.
The addition of stainless steel flexible coverings replacing rubber boots over joints in the main condenser air ejection system appeared to reduce inleakage by a
small amount.
The source of the D.O.
and also of carbon dioxide was attributed by the licensee to be residual fouling of condenser water boxe No sludge lancing of Unit 1 steam generators had occurred since the date of IR Nos. 50-335/87-24, 50-389/87-23 (November 2-6, 1987).
Unit 2 steam generators were sludge lanced during the outage of Unit 2 which was ongoing at the time of thi s inspection.
Results of Unit 2 lancing were 200 pounds of sludge from one steam generator (not otherwise identified)
and 150 pounds from the second steam generator or a total of 350 pounds.
Since only 222 pounds of sludge had been removed from Unit 2 steam generators during the previous (thi rd) refueling outage and only 30 pounds during the second refueling outage, it would appear that the quantities of sludge continued to increase for Unit 2, despite strict adherence to SGOG/EPRI recommendations.
Licensee representatives suggested that a
certain minimum level of D.O. might be needed to maintain protective oxide coatings in steam piping systems.
Nakeup water processing had been improved to the point where levels of chloride, sulfate and sodium in the makeup water were at levels of less than 2 ppb.
Unit 2 had been operating with water of this quality since startup while early operation of Unit
had been performed with lower quality water.
Up to the time of inspection, no defects attributable to'hemi stry had been observed in Unit 2, while Unit
had many such problems.
A licensee representative stated that licensee management was considering chemical cleaning of Unit 1 water systems to.permit Unit 1 to take full advantage of the high purity water available as one means of minimizing future chemical attack on plant systems and extending useful plant life.
Secondary water system pH in feedwater was 9.6 at the time of the inspection and the licensee was considering raising the level to 10. While this value would exceed the upper l imit of the current SGOG/EPRI guidelines, the licensee was coordinating the increased pH program with SGOG/EPRI to determine if higher pM in plants having no copper-containing components would expedite dissolution and transport of residual copper that had been plated on Unit 1 ferrous components prior to the 1981 replacement of all copper tubes in the system.
The licensee had also done a
CFR Part 50.59 safety evaluation on the proposed use of the higher level of pH.
The inspector reviewed the chemistry training and re-training programs and reviewed training records of all chemistry personnel currently assigned to chemistry duties.
At the time of the inspection, the training program consi,sted of 104 separate modules.
Fully qualified chemists were required to complete a minimum of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of formal training per calendar quarter; a review of training records for 1988 indicated than an average of 16 to 2G hours of training was completed for each qualified chemist.
New or partially-qualified chemists received from 200 to more than 600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br /> of chemistry training during CY 1988.
The inspector also reviewed selected chemistry procedures and and chemistry training modules.
All material appeared to be comprehensive and well-prepared and had been reviewed and approved in accordance with Technical Specification and plant requirement Several items, of new or updated chemistry analytical equipment had been procured and placed in service since IR Nos.
50-335/87-24 and 50-389/87-23 (November 2-6, 1987).
Two Nuclear Data Model 9900'ultiple channel analyzers for gamma radiation spectra had been installed in the plant chemistry counting room and a third unit was used in the plant Training Center.
A new Dionex Ion Chromatography unit had been installed in the chemistry laboratory for sodium analysis and a
new total organic carbon (TOC)
analyzer was in use.
A new digital atomic abso. ption (AA)
spectrophotometer was installed in the primary coolant chemistry laboratory.
On-line monitoring equipment recently installed included digital conductivity monitors in the water treatment plant to provide improved readout of low levels and cation conductivity meters on each condenser hot well, on each steam generator and on each steam generator blowdown line.
A silica monitor was planned for the water treatment plant.
No violations or deviations were identified.
Liquid Radwaste Processing (84750)
The licensee's liquid radwaste processing system'onsisted of two large-capacity demineralizer vessels connected in series.
The first vessel had a resin capacity of 50 ft~ and was typically loaded with 35 ft~
of nuclear grade mixed bed resin and topped-off with 15 ft~ of granulated activated charcoal.
The second, or downstream, vessel had a-35 ft~
capacity and was usually loaded with 35 ft~ of nuclear grade mixed bed resin.
The licensee found that using the two resin beds in series in a
once-through mode of operation did not provide sufficient decontamination factor (DF) to enable the plant to obtain a sufficiently low annual total radioactive liquid discharge.
However,, it was found that if a batch of liquid waste was continuously circulated through the system, the resultant product could be reduced in radioactivity content by as much as a factor of ten.
Cobalt and antimony nuclides were problems in radwaste cleanup because ion exchange resins seemed to have little effect..
A licensee representative stated that the use of a
charcoal pre-filter seemed to reduce cobalt output but did not have a significant effect on antimony.
The 50 ft resin vessel had a wider body than the 35 ft~ vessel; use of the 50 ft~ vessel as the upstream bed apparently reduced pressure drop (delta p) across the system as compared to when the 35 ft~ vessel was used in the upstream position.
A typical change of resins lasted about eight weeks, at which time both beds were changed.
A total of four vessels (two, 50 ft and two 35 ft~ vessels)
was used, with each set of two beds being used alternately as the "in-service" or "standby" set.
't Resins were not regenerated when depleted.
Depleted resins were transferred into 180 ft~ high integrity containers (HICs) for disposal at a
licensed burial site.
Each HIC was prepared for loading by placing approximately 10 ft~ of new cation resin in the bottom of the HIC; this was for the purpose of retaining water released from the resins in the dewatering process.
Since some of the resins placed in the HICs were from
the chemical and volume control system (CVCS), they often contained high-concentrations of Co-60 and Cs-137.
Prior to using the
fthm of new resin in the bottom of the HIC, liquid draining from CYCS resins could accumulate in the bottom of the HIC, subsequent to the dewatering process, and could result in rejection of the waste shipment at a licensed burial ground because free-standing water.
Since the use of the cation resin was adopted, no further problems were detected.
The inspector was told that the licensee had adopted a practice of a
36-hour hold after reactor shutdown before the reactor vessel top could be removed.
During the 36-hour hold, the CVCS was utilized in a
recirculating mode to decontaminate the primary reactor coolant system.
This reduced the dose equivalent iodine (DEI) concentration down to the 1E-03 uCi/ml range, as wel,l as reducing other radionuclide concentrations, minimizing the need for respiratory. protection and decreasing personnel radiation exposures during the early phases of refueling shutdowns.
No violations or deviations were identified.
Gaseous Radwaste Processing (84750)
The inspector reviewed leak tests of high-efficiency, particulate air (HEPA) filters and charcoal
'adsorbers in plant ventilation exhaust filtration systems and in control room emergency (habitability) air cleanup and supply systems.
The inspector also reviewed test results for methyl iodide retention of charcoal samples taken from the various ventilation treatment systems.
Unit 1 tests were performed in July 1988, and Unit 2 tests in January-February 1989.
The tests all appeared to have been performed satisfactorily, although some systems had to be re-checked after replacement of HEPA filters or charcoal which did not pass the original testing.
No violations or deviations were identified.
Post Accident Sampling System (PASS)
(84750)
l The inspector examined both Post Accident Sampling Systems (PASS),
accompanied by a licensee representative.
The representative explained the functioning of the system and the principal differences between the systems.
It should be noted that the Unit
PASS was supplied by the Milton Roy Company while the Unit 2 PASS was supplied by the Combustion Engineering Corporation.
The two systems have many similarities and certain components are essentially identical; however, the system differences are large enough to require that chemistry personnel qualify on the operation of both units separately.
A licensee representative noted that both PASS units were partially inoperative with respect to sampling and measuring the dissolved hydrogen gas content of a primary coolant sample.
The licensee was in the process of replacing both hydrogen sampling and measurement systems with a
Whitaker Industries
"ECOSENSOR" hydrogen analyzer.
The initial schedule
had projected installation of the new analyzer in the, Unit 2 PASS during the refueling outage which was in its final phases at the time of this inspection; however, the vendor was unable to meet. the requested delivery date.
Preliminary work on the Unit 2 PASS modification had been completed up to the point where the new analyzer was the next thing to be installed but since delivery had not been made, the project was halted at that point.
A new completion date had not been determined as of the end date of this inspection.
Installation of a
new hydrogen analyzer in the Unit
PASS was scheduled for a Unit 1 outage in 1990.
Despite the inoperable condition of the inline hydrogen monitoring function, the licensee retained the capability of performing grab sampling and doing the requisite analysis from the grab sample.
In order for plant chemists to maintain proficiency on the PASS, each analyst was annually required to operate all PASS functions and collect a
sample of primary coolant.
Each sample was then analyzed for boron, pH, dissolved gas (hydrogen),
dissolved oxygen (D.O.), gross radioactivity,
.and iodine-131.
Each analyst was required to log-in his/her results in the Annual PASS Operability Log.
No violations or deviations were identified.
Liquid and Gaseous Radioactive Effluent Monitoring (84750)
The inspector reviewed calibration data and calibration and functional testing of the Unit 2 plant vent monitor and wide-range gas monitor (WRGM).
The tests were conducted on March 14, 1989, using NBS-traceable Cs-137 and Ba-133 solid sources and plant gas samples analyzed on a
MCA which was calibrated to a NBS-traceable standard.
The tests appeared to be complete and were performed in accordance with approved procedures.
No violations or deviations were identified.
Meteorological Monitoring Systems (84750)
The inspector reviewed Plant Change Modification (PCM) 109-987.
The PCM, which had not received final administrative approval as of the end date of this inspection, called for replacement of the current meteorological tower and all associated equipment, such as the principal detection and measurement devices, data processing systems, display, recording and data transmission systems.
All equipment was to meet the criteria or requirements of Regulatory Guide 1.23,
CFR Part 100. 10,
CFR Part 100. 11, and Appendix I to 10 CFR Part 50.
In the Unit 1 Control Room, all existing meteorological display equipment was to be replaced with a multiple point digital readout recorder, with the Unit 1 safety parameter display system (SPDS) to be used for primary meteorological data display.
All Unit 2 Control Room meteorological
equipment was" to be removed, leaving only the Unit
SPDS for data display.
The PCM projected start of tower construction in early July 1989 prior to the anticipated heavy thunderstorms typical of the August-September time period.
No violations or deviations were identified.
9.
Semi-annual Radioactive Effluent Release Reports (84750)
The inspector reviewed the licensee's Semi-Annual Radioactive Effluent, Release Reports for the periods January through June 1988, and July through December 1988 and discussed the report contents with licensee representatives.
The reports appeared to be complete and appeared to contain the information requested in the guidance of Regulatory Guide 1.21.
The licensee reported no unplanned releases for the year.
The inspector's review included a comparison of the radioactive effluent releases for Calendar Year (CY)
1988 relative to reported releases for previous years.
A tabular summary of.releases for CY )985 and CY 1988 is shown below:
GASEOUS EFFLUENTS:
MIXED FISSION PRODUCTS AND ACTIVATION PRODUCTS, CURIES/YEAR 1985 1988 Unit
Unit 2 50,800 9,550 1,420 9,160 LIQUID EFFLUENTS:
MIXED FISSION PRODUCTS AND ACTIVATION PRODUCTS, CURIES/YEAR 1985 1988 Unit
Unit 2 2.72 2.75 0.264 0.259 The inspector noted that liquid effluents for CY 1988 from Units 1 and
had been reduced by more than a factor of ten, relative to CY 1985 releases and that Unit
gaseous releases for 1988 were lower than 1985 releases by a factor of more than 35.
Unit 2 gaseous releases, however, were basically the same for 1985 and 1988, for reasons discussed below.
Reductions in liquid releases were. attributed to a
number of remedial actions initiated by the licensee since 1985 including a plant-wide liquid leak reduction program, improved methods of operating waste water cleanup demineralizer beds, and better control of spent-resin dewatering proces Unit 1 radioactive gaseous releases were reduced through programs for the
"reconstitution" of fuel by removing and replacing identified defective fuel pins and by re-designing the fuel pin configuration to incorporate a
solid zircaloy section at the lower and of the fuel pins where most of the damage in earlier-fuel cycles had been observed.
The licensee had also initiated a much slower ramp to power than had been previously used.
The success of these three measures was indicated in the dramatic decline in quantities of noble gases emitted from Unit 1 during CY 1988.
At the time of this inspection, the licensee was in the final stages of a refueling shutdown of Unit 2, during which substantial fuel reconstitution had been performed and a substantial portion of the reactor's fuel had been replaced with the same type of new-design fuel used earlier in Unit 1.
The licensee anticipated that in CY 1988 Unit 2 gaseous'releases would be reduced by at least a factor of five relative.to CY 1988.
Prior to the current refueling outage, Unit 2 had not undergone any significant amount of fuel reconstitution and had none of the newer type fuel installed in its core.
It should be pointed out that while St.
Lucie liquid and gaseous radioactive effluent releases were much higher in previous years than in 1988, the radiation doses calculated in the environs of the plant as a
result of the releases for each year, were a
small fraction of MPC and well within the established regulatory limits for radiation dose.
The 1988 releases from St.
Lucie, Units 1 and 2, were also compared to the reported releases from all RII PWRs in 1988.
GASEOUS EFFLUENTS CY 1988 REGION II PWRs Ci/Yr/Unit St.
Lucie -
J St.
Lucie -
J Median, RII f
Maximum RII I
I PWRs I
PWRs Mixed Fission(
1.42E+03 Products and Activation Gases 9. 16E+03 1.56E+03 9. 16E+03
) Iodine-131 and]
6.4E-03 ( Parti cul ates
[with Half-
) lives > 8 days',
I 2.85E-02 4. 8E-03 6.26E-02
LI UID EFFLUENTS CY1988 - REGION II PWRs Ci/Yr/Unit St.
Lucie -
f St.
Lucie -
J Median, RII f
Maximum RII I
I
'
PWRs i
PWRs Mixed Fission[
2.64E-01 Products and Activation Products 2.59E-01 5. 42E-01 2.57E+00 Tritium 2.75E+02 2.75E+02 3.53E+02 9.70E+02 In releases of gaseous radioactive effluents; St. Lucie, Unit 1, was slightly lower than the median for RII plants, while St.
Lucie, Unit 2, had the highest releases of any RII PWR unit.
However, another multiple-unit site had higher total site gaseous releases than the St.
Lucie site.
For gaseous releases of Iodine-131 and particulates with,half-lives greater than 8-days, St. Lucie, Unit 1, was about 30>< higher than the RII median while St.
Lucie, Unit 2, was the fourth highest unit in such releases in RII.
In discussions of the above data with licensee representatives, the inspector agreed that actions already taken by the licensee during the ongoing refueling shutdown of Unit 2 would likely result in significant reductions of effluents from Unit 2 in CY 1989.
Liquid radioactive effluents from St.
Lucie, Units
and 2,
were substantially lower than median values for all RII PWRs in 1988.
Releases of mixed fission products and activation products were less than one-half of reported median values and a factor of ten less than the reported maximum values.
As was noted above in the compari son of 1988 St.
Lucie liquid-releases with past years'xperience at St. Lucie, the licensee had taken effective corrective measures in 1986 and 1987 to improve liquid radwaste treatment system performance.
The inspector concluded that the licensee's good performance in holding liquid effluents at a low level in 1988 was largely attributable to continued application of the earlier corrective measures and to quality assurance measures taken to assure effective performance.
The Semi-Annual Radioactive Effluent Release Reports for January-June 1988 and July-December 1988 were found to be acceptable.
No violations or deviations were identifie Confirmatory Measurement Results (84750)
As part of the NRC Confirmatory Measurements Program,,
spiked liquid samples were sent to the licensee on January 9,
1989, for selected radiochemical analyses.
The licensee's analytical results were transmitted to RII by letter dated March 14, 1989.
A omparison of the licensee results to
.he known values is presented in Attachment 1.
The acceptance criteria for the comparisons are listed in Attachment 2.
Comparative results were in agreement for all of the four requested analyses (H-3, Fe-55, Sv-89, and Sr-'90).
All presented data should be reviewed by cognizant licensee staff members for significant
- trends in the data for the successive years in which spiked samples were analyzed.
A senior member of the licensee Chemistry staff was informally notified of the results -in a telephone'ommunication on April ll, 1989.
No violations or deviations were identified.
Exit Interview The inspection scope and results were summarized on April 7, 1989, with those persons indicated in Paragraph 1.
The inspector described the areas inspected and discussed in detail the inspect,ion results listed below.,
Although proprietary information was reviewed during this inspection, none is contained in this report.
Dissenting comments were not received from the licensee.
Since 1985-1986, the licensee had reduced plant liquid radioactive effluents for 1987 and 1988 by a factor of ten and had reduced Unit
gaseous releases by a factor of 36 over 1985 releases.
Liquid releases had been reduced by applying more intensive ion exchange techniques, while ghseous releases were reduced through fuel reconstitution and fuel re-design.
Unit 2 gaseous releases remained at about the 1985-1986 level for 1988 but measures taken during the current refueling of Unit 2 were expected to have an impact on reducing future Unit 2 gaseous releases.
The 1988 Semi-Annual Effluent Release Reports were reviewed and found to be adequate.
Reviews of radioactive effluent instrumentation, post-accident sampling systems,, air cleaning systems, the plant meteorological equipment upgrade program, and training showed all programs to be adequate.
The chemistry and radiochemistry programs were considered to be licensee strengths, as were the quality assurance and quality control programs which were contributed substantially to the performance of the chemistry group.
The water chemistry control programs enabled the plant to meet or exceed SGOG/EPRI guidance.
The chemistry department had taken a number of innovative approaches to the improvement of plant water chemistry which appeared to have resulted in decreases in piping corrosion, decreases in
worker radiation dose during plant outages and decreases in plant radioactive effluents.
No violations or deviations were identifie ATTACHMENT 1 CONFiRMATORY MEASUREMENT OF H-3, fe-55, Sr-89, AND Sr-90 ANALYSES FOR ST.
LUCIE NUCLEAR PLANT ON JANUARY 13, 1989
~isoso e
Licensee
~uCi mi NRC
~ue mi Resolution Ratio Licensee NRC C~om artisan H-3 Fe-55 Sr-89 Sr-90
37E 05 1. 43E-05 6.28E"05 3.<<E-06 1.55+0.05E"05 1.68+0.05E-05 6.6~I+0.20E-05 3.59+0.14E-06
3l<
26 0. 88 0.91 0.95 0.95 Agreement Agreement Agreement Agreement
,I