ML20040C751
| ML20040C751 | |
| Person / Time | |
|---|---|
| Site: | Byron, Braidwood, 05000000 |
| Issue date: | 01/13/1982 |
| From: | Tramm T COMMONWEALTH EDISON CO. |
| To: | Harold Denton Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 8201290201 | |
| Download: ML20040C751 (91) | |
Text
. _ _.
D Commonwealth Edison
) One First National Plaza. Chicago, Imnois C"
O" Address Reply to: Post Office Box 767 Chicago, Illinois 60690 January 13, 1982 19 o
vg Mr.. Harold R.
Denton, Director pg{ gg M_
Office of Nuclear Reactor Regulation g.
U.S. Nuclear Regulatory Commission JAN 281962>-
Washington, DC 20555 n amn fatm"f6A J ~
yn' W (%
v axrit t Sub ect:
Byron Station Units 1 and 2
%gp J
Braidwood Station Units 1 and 2 Co Advance FSAR Information tu8 NRC Docket Nos. 50-454/455/456/457
Dear Mr. Denton:
This is to provide advance copies of information which will be ' included in the Byron /Braidwood FSAR in the next amendment.
Attachment A to this letter lists the information enclosed.
Ore (1) signed original and fif ty-nine (59) copies of this letter are provided.
Fifteen (15) copies of the enclosures are included for your review and approval.
~
Please address further questions to this office.
Very truly yours, fb b&
j
[ T. R.
Tramm Nuclea r Licensing Admini strator i
Pressurized Water Reactors
' Attachment l
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t I-f 8201290201 820113 PDR ADOCK 05000454 A
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ATTACHMENT A LIST OF ENCLOSED INFORMATION I.
FSAR Question Responses Revised:
010.50 022.25 040.120 421.22 II.
FSAR Text Changes Pages for Table 6.2-58 Chapter 14 Preop and Startup Tests Page 15.B-6 III.
Miscellaneous Items RSB Open Items (3)
Preservice Examination of Steam Generator Tubing ASB Open Item Financial Qualificaiton Question 1-A 1
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B/B O
Reactor Systems Branch Open Items
()
Charging Pump Miniflow Isolation Valves 1.
Address the concern of post-accident recirculation fluid
.being transferred to the RWST via the charging pump mini-flow lines following a small break LOCA with repressuriza-tion to above the RCS pressure setpoint that requires the operator to reopen the miniflow isolation valves.
Response
The miniflow is directed to the VCT not the RWST.
2.
Provide a comparison of the flow rate through the mini-flow line to total flowrate.
Response
At full RCS pressure there is a nominal 60 gpm flow throu~gh the miniflow line.
There is a decrease in flow to a nominal 28 gpm at the full charging pump flow of 550 gpm.
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3.
Provide a permanent fix to resolve the concern.
Response
C$
We have not determined the exact design to be employed at the Byron /Braidwood plants to insure minimum charging pump flow following a secondary side high energy line rupture.
However, we anticipate adding a relief valve or valves to the miniflow lines with a set pressure established to prevent the charging pump from reaching a dead head condition.
B/B PRESERVICE EXAMINATION OF STEAM GENERATOR TUBING l
Prenervice eddy current examinations will be conducted on 100% of all the tubing in each steam generator (model D4).
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B/B Auxiliary Systems Branch Open Item Auxiliary Feedwater System O
Technical Specifications Commonwealth Edison will provide Technical Specification changes to impose the following restrictions.
21.
A 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> time limit for inoperability of one auxiliary feedwater pump per Unit.
(LCO change) 2.
A seven day time limit for inoperability of the opposite unit's
'A' Diesel / Generator (LCO and Bases change)
If either of the two time limits are exceeded the plant will be placed in the hot shutdown condition.
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Closed Closed Closed N/A N/A N/A M
M N/A 54 13 Air 1/2 M-105-3 Iv0018 Outside Yes MIN.
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Closed Closed Closed N/A N/A N/A M
M N/A 54 Air 1/2 M-3 IVQ019 m iside Yes MIN.
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Closed Closed Closed N/A N/A N/A M
M N/A 12 M-46-1 13 M-46-1 18 M-46-1 57 15
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HYDROGEN 56 12 Hy4 Air 3/8 M-68-7*
IPS22Ph Outside Yea Glote S
Open Closed Closed As-is T
A RM IE H + Air 3/8 M-68-7 1PS229% Outside va9 Globe S
Open Closed Closed As-1g' T
- A RM. 1 E MONITOR 56 12 H + Air 3/8 M-68-7 1PS2 3rA Outside veg G?obe S
Open Closed Closed Closed T
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A set 1g 56 31 H2+ Air 3/8 M-68-7 1PS 2 3-Outside ? cts Globe S
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A RM 13 H + Air 3/8 M-68-7 1PS231 2nside va't st /A Check N/A, If/A N/A N/A N/A N/A
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l B/B-FSAR AMENDMENT 36 O
JANUARY 1982 lower than that required by Technical Specifications, ON or if after fuel movement has ceased, the nuclear monitoring channels indicate that the reactor is critical or continues to approach criticality.
Concentrated boric acid from the boric acid tanks shall be added to the vessel through the emergency boration valve and the RCS charging pumps.
Boration shall continue until the required shutdown status is achieved.
Containment evacuation will be carried out in accordance with evacuation procedures.
Acceptance Criteria The initial core loading is completed in accordance with the initial core loading sequence defined by Westinghouse.
O 14.2-74a
B/B-FSAR Os i
TABLE 14.2-63 CONTROL ROD DRIVES
(_/
(S.tartup Test)
Plant Conditions or Prerequisites 1
Prior to initial criticality.
Test Objective To check the controlling features, adjust setpoints, and to verify rod speeds and sequencing of power to the rod drives.
Test Summary During rod withdrawal, following core loading and installa-tion of the rod mechanisms, operation of the control rod mechanisms will be verified under the conditions set forth in FSAR Subsection 4.2.4. 3.
Acceptance Criteria The control rod drive mechanisms operate over the full range of travel and that rod speeds are in accordance with subsections 3.9.4.2 and 4.2.4.3.
O 14.2-75
B/B-FSAR 73
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TABLE 14.2-64 ROD POSITION INDICATORS
'T (Startup Test)
Plant Condition or Prerequisites Prior to initial criticality.
Tert Objective To calibrate the control rod position indicators.
Test Summary Following core loading and installation of the rod mechanisrs, the control rods will be operated over their full range of travel.
The rod position indicators will be calibrated over the rod full travel range.
Also bank insertion alarms, deviation alarms and rod bottom bistable setpoints and alarms will.be demonstrated to be within limits specified in the.
FSAR.
Acceptance Criteria The control rod position indicators are calibrated in
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accordance with Subsection 7. 7.1.3. 2.
O 14.2-76
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B/B-FSAR AMENDMENT ~36 JANUARY 1982 P
TABLE 14.2-65 REACTOR TRIP CIRCUIT (Startup Test)
Plant Conditions or Prerequisites Prior to initial criticality.
Test Obiective To verify the reactor protection circuits in the various modes of tripping.
Test Summary operational testing will be conducted to verify the reactor protection circuits in the various modes of tripping, including manual reactor trip up to the tripping of the reactor trip breakers.
Acceptance Criteria The reactor trip circuits operate in accordance with Sub-section 7.2.1.1.2.
The purpose of this test is to demon-trate that. the various reactor trip circuits are operational.
O 14.2-77
h B/B-FSAR AMENDMENT 36 JANUARY 1982 O
TABLE 14.2-66 ROD DROP MEASUREMENTS (Startup Test)
Plant Condition or Prerequisites Prior to initial criticality.
Test Objective To measure rod drop times at cold no-flow, cold full-flow, hot no-flow, and hot full-flow plant conditions following core loading.
Test Summary The drop time for each control rod will be measured at cold no-flow, cold full-flow, hot no-flow, and hot full-flow conditions.
All rods falling outside the two-sigma limit will be retested a minimum of three additional times each.
The drop time will be measured from the decay of the stationary gripper coil voltage until the rod enters the top of the dashpot.
The RCCA drop traces will confirm proper operation of the decelerating devices.
(
Acceptance Criteria The rod drop time is verified to be less than the maximum value specified in Subsection 3.9.4.3.
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14.2-78
B/B-FSAR i
TABLE 14.2-67 INCORE FLUX MONITOR SYSTEM (Startup Test)
Plant Condition or Prerequisites Prior to initial criticality.
Test ob-iective To verify indexing and to ensure free passage of detectors into all positions.
t Test Summary Prior to core loading the moveable detectors systems will be operationally checked out in all modes of operation.
Following
]
core loading and insertion of the detector thimbles, the system will again be operationally checked out by ensuring the free l
passage of detectors into all insertion thimbles.
Electrical tests will be performed using simulated signals to check out the recorders.
During physics measurements the system is operationally checked while obtaining flux maps.
Acceptance Criteria The incore flux monitor system operates in accordance with Subsections 7.7.1.9.2 and 7.7.1.9.3.
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14.2-79
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B/B-FSAR TABLE 14.2-68
(
NUCLEAR INSTRUMENTATION (Startup Test)
- Plant Condition or Prerequisites After startup and during escalation.
Test Objective To verify overlap between the source, intermediate and power range channels, and to verify alarm and protective functions.
Test Summary Data will be taken to verify overlap between source and intermediate, and between intermediate and power range channels after initial criticality and during power escala-tion.
This data will be collected until the overlaps are firmly established.
Alarm and protective functions will be verified.
During low power escalation, the power _ range detector currents will be monitored and compared with the intermediate range currents to verify response of the power range detectors.
The power range nuclear channels will be
(~hs-)
secondary plant feedwater flow, feedwater temperature, and calibrated to reactor thermal output based on measurement of steam pressure.
Acceptance Criteria Approximately 1 1/2 decade overlap is observed between all channels and trip setpoints are in accordance with the Technical Specifications in Chapter 16.0.
O 14.2-80 m
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B/B-FSAR AMENDMENT 36 JANUARY 1982 f^h
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TABLE 14.2-70 REACTOR COOLANT SYSTEM FLOW V
(Startup Test)
(Plant Condition or Prerequisites Priar to initial criticality at hot shutdown.
Test Objective To determine reactor coolant flow and flow coastdown times.
Test Summary Following core loading, measurements will be made of elbow tap differential pressure instrument voltages to make relative comparison.
At hot shutdown conditions following core loading, measurements of loop elbow differential pressure drops are made at various flow conditions.
This data will be used with the reactor coolant pump performance curve to calibrate flow.
Data vill be taken to ensure that loop and core flows are within their required minimum and maxinum flows and that flow coastdown times are in accordance with accident analysis assumptions.
Data will be taken to ensure pump performance, rotational speed and indicated flow are consistent with performance curves.
Vibration monitoring of the reactor coolant pumps will be done using 2 IRD pickups mounted to the motor supports (90 degrees apart in the horizontal plane).
In. addition, baseline vibration data on the pumps will be obtained using i
a portable IRD vibration measurement unit.
These will be taken at bearing points on the motor (in three directions, i
where possible) during the preoperational test.
Acceptance Criteria The calibrated flows and coastdown times are verified con-servative with respect to Subsection 5.4.1.3.2 O
14.2-82
B/B-FSAR TABLE 14.2-71 PRESSURIZER EFFECTIVENESS (Startup Test)
Plant Condition or Prerequisites At hot shutdown following core loading.
Test obiective To demonstrate the ability of the pressurizer heater to maintain and increase system pressure, and of the spray system to reduce system pressure.
/
Test Summary At hot no load temperature and pressure the effectiveness of the pressurizer heaters in maintaining and increasing system pressure will be demonstrated.
The heaters will be energized and the pressure compared to the predicted pressure rise.
The ability of the spray system to reduce system pressure will be demonstrated.
The spray valves are opened and the pressure decrease compared to the expected pressure decrease.
Acceptance Criteria The pressurizer is able to maintain, increase, or lower system pressure in accordance with Subsection 7.7.1.
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14.2-83 1.-
NSAM
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TABLE 14.2-72 WATER CHEMISTRY (Startup Test) 1 Plant Condition or Prerequisites Prior to heatup following core load, prior to criticality, at criticality, and during power escalation.
Test objective Chemical analyses of the reactor coolant are performed to verify that plant chemistry is within specification and can be maintained within specification.
Test Summary Water for reactor coolant system fill and makeup will be analyzed for chloride content, conductivity, total dissolved solids, pH, clarity, and fluorides.
Prior to, at criticality, and during power escalation, chemical analysis will be perf ormed to verify requirements.
During low power physics tests and at approximately 30, 50, 75, and 100% power, samples of reactor coolant will be taken and analyzed to verify that coolant chemistry requirements can be maintained.
kcceptanceCriterb Water chemistry is in accordance with Technical Specifications, Chapter 16.0.
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TABLE 14.2-74 EFFLUENT RADIATION MONITOR (Startup Test)
Plant Condition or Prerequisities During or prior to lower power tests and during power escalation.
8 Test Objectives To verify proper operation of process and effluent radia-tion monitors.
Test Summary Process and effluent monitors will be checked for proper response under normal operating conditions.
Acceptance Criteria The process and effluent radiation monitors are operable in accordance with section 11.3.
To the extent practical, laboratory analyses of samples from process and/or ef fluent 3
systems will be made.
Results of the analyses will be compared
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to the response setpoint of the radiation monitor to deter-mine accuracy of the monitor.
Note:
Area Radiation Monitors are covered by a p.eopera-tional Test.
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O 14.2-86
B/B-FSAR AMENDMENT 36
[V
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JANUARY 1982 or understood and considered not to adversely affect
("'T.
the safety of continued operations.
U c.
The following reactivity addition sequence will be used to assure that criticality will not be passed through on a period shorter than approximately 30 seconds:
Nuclear monitoring data will be analyzed concurrent with RCS boron dilution to permit accurate predictions of the conditions under which criticality is expected j
to occur.
If, during RCS boron dilution, the nuclear monitoring data indicate a significant departure from expected response, dilution will be terminated until the source of the unexpected response is corrected, or understood and considered not to adversely affect the safety of continued operations.
When the Inverse Count Rate Ratio (ICRR) from any nuclear monitoring channel reaches approximately 0.1, the RCS dilution rate will be reduced to approx-imately 30 gpm, and nuclear monitoring ICRR data will be obtained and renormalized to 1.0.
Dilution at this new rate will be continued until criticality is achieved.
If criticality will be achieved by withdrawing control rods, the following will be followed:
When the ICRR reaches approximately 0.3 (after renormalization), the dilution will be terminated and approximately 15-30 minutes of waiting will be undertaken to permit RCS mixing.
Control bank D will then be withdrawn incrementally until criti-c.ality is achieved.
Acceptance Criteria The plant is critical with the flux level at approximately lx10-8 amps on the intermediate range nuclear channels.
O 14.2-87a
B/B-FSAR
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TABLE)4.2-81 PSEUDO ROD EJECTION (Startup Test)
Plant Condition or Prerequisites Hot zero power and at approximately 30% power during power a scer.sion.
Test Obiective To verify hot channel factors and rod worth with a rod cluster control assembly (RCCA) withdrawn from its bank position.
Test Summary
~~~
Incore measurements will be made w5th the most reactive RCCA l
withdrawn from its bank position to determine the resulting hot channel factors.
The worth of the most reactive RCCA will be verified to be conservative with respect to the acci-dent enalysis.
Measurements will be made using the incore flux monitoring system.
Tests will be run at hot zero power and at approximately 30% reactor power.
O cceptable Criteria A
Hot channel factors and rod worth are in accordance with Section 4.3.
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14.2-93
D/B-FSAR AMENDMENT 36 O
JANUARY 1982 (m)
TABLE 14.2-82 POWER REACTIVITY COEFFICIENT MEASUREHENT (Startup Test)
Plant Condition or Prerequisites During power level changes at approximately 30, 50, 75, and 100%
reactor power.
Test Obiective To determine the power coefficient of reactivity and power defect.
Test Summary Duing power level changes when the reactivity effects of xenon can be adequately accounted for, measurements will be made of reactor power and associated reactivity changes as follows:
Reactor thermal power will be determined using calorimetric data.
Associated reactivity changes will be measured by reactivity ~ computer response and the response of T,yg and delta T recorders.
( ) The power coefficient of reactivity and power defect will be determined from these measurements.
Acceptance Criteria The power reactivity coefficient is within values used in Subsection 4.3.2.3.3.
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14.2-94
d' B/D-FSAR TABLE 14. 2-84 FLOX..'LSYMMETRY EVALUATION (Startup Test)
Plant Condition or Prerequisites Reactor at approximately 30% and 50% power.
Test Obiective To determine the response of excore nuclear detectors under asymmetric power distributions.
Test Summary Pseudo rod drop tests will be performed at approximately 30% and 50% reactor power to determine the response of the excore nuclear detectors.
Acceptance Criteria The excore nuclear instrumentation can detect an. asymmetric power ~
distribution in accordance with Subsection 7.7.1.3.1.
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D/B-FSAR
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TABLE 14.2-85 TURBINE TRIP (Startup Test)
Plant Condition or Prerequisities At 100t power.
Test Objective To verify the ability of the primary and secondary plant and the plant automatic control systems to sustain a trip' from 100% power and to bring the plant to stable condition following the transient.
Test Summary The plant will be brought to normal steady-state full power conditions with the auxiliary electrical loads supplied from the system auxiliary transformer.
The plant will be tripped by manually tripping the turbine from the turbine control station.
The parameters to be monitored will include nuclear flux; reactor coolant loop temperature; pressurizer pressure and level; steam generator level, steam flow, and feed flow; reactor trip breaker operation; and controlling group rod position indication.
The parameters will be selected to determine the response of the plant control systems.
Acceptance Criteria The acceptance criteria that must be met to successrully complete the turbine test are:
a.
the pressurizer safety valves shall not lift; b.
the steam generator safety valves shall not lift; c.
Safety Injection shall not be initiated; d,
nuclear flux must drop to 15% within the time limit specified by the Westinghouse Setpoint Study after initiation of the turbine trip; e.
all control rods must release and drop; and f.
no water hammer in the steam generators and/or feedwater system shall occur.
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14.2-97
B/B-FSAR
)
TABLE 14.2-86 SHUTDOWN FROM OUTSIDE THE CONTROL ROOM
()
(Startup Test)
Plant condition or Prerequisites Above 10% reactor power.
Test Obiective To demonstrate that the plant can be maintained in hot shutdown f rom outside the control room.
Test Summary When above 10% power, the plant will be tripped and the plant maintained in hot shutdown for a period of time from outside the control room.
Acceptance criteria Data obtained from outside the control room demonstrates:
1.
The plant is tripped and in a stable hot shutdown condition for 30 minutes.
2.
The capability for cold shutdown from the hot shutdown condition:
a.
Reactor coolant temperature and pressure can be lowered to permit operation of the core decay heat xemoval system.
b.
Operation of the decay heat removal system can be initiated and controlled, c.
A heat transfer path to the ultimate heat sink can be established.
d.
Reactor coolant temperature can be reduced approxi-mately 50* F using the decay heat removal system at a rate in accordance with the Technical Specifications, Chapter 16.0.
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14.2-98
B/B-FSAR AMENDMENT 36 JANUARY 1982 TABLE 14.2-87
()
LOSS OF OFFSITE POWER (Startup Test)
Plant Condition or Prerequisites Above 10% power.
Test Objective To demonstrate starting of emergency diesels, stripping of vital buses, and sequencing loads on vital buses following a trip of the plant without an available offsite source of power.
Test Summary At above 10% power, a generator trip will be initiated with-out an offsite source of power being available.
Starting of the emergency diesels, stripping of vital buses, and sequencing of emergency loads on the vital buses will be demonstrated.
The test will be of sufficient duration to ensure that the necessary equipment, controls and indication are unavailable following the blackout to remove dacay heat from the core O
using only~ emergency power suppl $es.
Acceptance Criteria i
The plant is shown to respond to a plant trip concurrent with loss of offsite power in accordance with Subsection 8.3.1.1.1.
l The duration of the blackout will be at least 30 minutes.
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14.2-99
B/B-Esem D
(v TABLE 14.2-88
/"N.
10% LOAD SWING t
()
(Startup Test)
Plant Condition or Prerequisites During power escalation.
Test Objective To demonstrate automatic plant response to a 1 10% step load change.
Test Summary Demonstrate plant response to a step load change of + 10%
at approximately 30, 75, and 100% reactor power.
Initiation of the leadswing will be accomplished with the DEH turbine generator controls.
The test will be conducted with the major control systems in automatic.
Acceptance Criteria a..
Reactor and turbine must not trip.
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b.
Safety injection is not initiated.
c.
Neither steam generator relief valves nor safety valves should lift.
d.
heither pressurizer relief valves nor safety valves should lift.
e.
No manual intervention should be required to bring plant conditions to steady state.
f.
Plant variables (i.e., Tavg, pressure, feed flow, steam flow, etc.) should not incur sustained or diverging oscillations.
g.
Nuclear power overshoot (.undershoot) must be less than the value specified by the Westinghouse Setpoint Study for load increase
(. decrease)..
%J 14.2-100
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TABLE 14.2-89 SOE LOAD REDUCTION (Startup Test)
Plant Condition or Prerequisites During power escalation.
Test Obiective To demonstrate manual and automatic plant response to a 505 load reduction.
Test Summary Demonstrate plant response to a 50% load reduction from approximately 100% reactor power.
Acceptance Criteria a.
Reactor and turbine must not trip.
b.
Safety injection is not initiated.
c.
Neither steam generator relief valves nor safety valves should lift.
d.
Neither pressurizer relief valves nor safety valves should lift.
e.
No manual intervention should be required to bring plant conditions to steady state.
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14.2-101
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B/B-FSAR AMENDMENT 36 O
JANUARY 1982 TABLE 14.2-90
()
RTD CROSS CALIBRATION (Startup Test) i
. Plant Condition or Prerequisites
. Prior to initial criticality.
Test Objective To provide data for the wide range RTD's, narrow range RTD's, and incore thermocouple calibration.
Test Summary At various plant temperatures the average RTD temperature will be compared to each RTD and incore thermocouple temperature to provide a basis for their calibration.
Acceptance Criteria The RTD's calibration data is taken.
The extrapolated 100% value of delta temperature for the average of all channels shall fall within 2' F of the value given in Q(,/
Precautions, Limitations, and Setpoints for the Westinghouse NSSS."
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r/B-FSAR p
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The peaking factor reduction required to maintain the 2200'F clad temperture limit is therefore the greater of
( )s AFQB and AFQ '
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or; AFQPENALTY " 0.118 B.
.The effect on LOCA analysis results of using improved analytical and modeling techniques -(which are currently approved for use in the Upper Head Injection plant LOCA ar.alyses but which are also applicable to Byron /Braidwood) ir. the reactor coolant system blowdown calculation (SATAN computer code) has been quantified via an analysis which has recently been submitted to the NRC for review.
Recog-nizing that review of that analysis is not yet complete and that the benefits. associated with those model improvements can change for other plant designs, the NRC has estab-lished a credit that is acceptable for this interim period to help offset penalties resulting from application of the NRC fuel rod models.
That credit for two, three and four loop plants is an increase in the LOCA peaking factor limit of 0.12, 0.15 and 0.20 respectively.
C.
The peaking factor limit adjustment required to justify plant operation for this interim period is determined as y
the appropriate AFQ credit identified in section (B)
)
above, minus the 6FQPENALTY calculated in section (A) above (but'not greater than zero)
I FQ ADJUSTMENT = 0.2 - 0.118 = 0.082 > 0.
Therefore FQ ADJUSTMENT = 0.0.
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(
B/B-FSAR
()
E.23 RELIEF AND SAFETY VALVE TEST REQUIREMENTS (II.D.1)
POSITION:
By letter dated July 1, 1981 (Rev. 4), R. C. Youngdahl.(Consumer Power) transmitted the Interim Data Report for the EPRI PWR
-Safety and Relief Valve' Test Program.
This report summarizes the test data collected to date on relief valves (safety valve t
data is still not available).
Byron /Braidwood plants have Copes-Vulcan Model D-100-160 2-inch air-operated globe relief valves (316SS w/ stellite plug and 17-4PH cage) and Crosby Model EP-BP-86, size 6M6 safety valves.
Results provided-in Section 4.6 of the EPRI Interim Data Report are applicable to Commonwealth Edison plants.
Preliminary evaluation of the data indicates that the relief valves will perform their intended function for steam inlet conditions.
Commonwealth
. Edison will submit preliminary and final evaluations, and other pinat specific data for all relief evaluations, and
~
other plant specific data for all relief and safety valve inlet conditions yet. to be tested on the schedule set forth in the September 29, 1981 letter.from D. G. Eisenhut to all licensees and applicants.
The PWR test program will be completed by April 1, 1982 and the plant specific submittals confirming the adequacy of the safety valve, relief valve, and piping design will be provided prior to fuel load of the first unit.
Regarding verification of block valve functionability, this topic is under discussion between the PWR utilities and the NRC staff.
Commonwealth Edison plans to abide by the final conclusions reached between the PWR owners and the NRC staff.
2 s
I a
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i E.23-1 i
i l
Financial Oualification Question 1-A O
January 7, 1982 1
BYRON GETERATING COST ESTIMATI'S Mr. T. R. Tramm:
The Generating Cost Estimates for Byron 1 and 2 requested by the NRC are attached.
Working papers are on file in this office and are available upon request.
H. A. Ziteerman O
Statistical Research Attachment
/
Approved:7/[
Ink l
i l
O c
l
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~.s-1.a.
ATTACHMENT FOR ITEM NO.
O ESTIMATED At'NUAL COST OF OPERATING NUCI E R GENERATIN Byron 1 UNIT:^ FOR THE CALEliDAR YEAR 19_84 (thousandsofdollars)
Operation and_.naintenance expenses Nuclear power generation 50 %)........... $ q. m c huclear fuel expense (plant f actor 24.576__
~
Other operating expenses.....................
14,650 __
Maintenance expenses.......................
94,o=
Total nuclear power generation.............
~
M[
Transmission expenses?.....'..............."....
P Ah nistrative and ceneVal expenses
~
6,789 Property and liability insurance.................
s. nc, Other A. &G. expenses.......................
14.e70 Total A.&G. expenses...
TOTAL 0&M EXP EN5ES............ '...... '...
107.960 O
47,438 Depreciation expense.........................
Taxes other than income taxes
- 5. Soc
~ Froperty taxes.............................
12,179_
Other................................
le,07u Total taxes other than income taxes...........
103,479 I n ccc e ta x e s - Fe d e ral.. <.....................
15,392 Inccce ta xes - other.........................
28,435
...'.......'.....~....;.._
Deferred income taxes - net 3,235
, Investment tax credit adjustments - net................ _ 246,412 16.17 % )........,..........
Return (rete of return:
570,415 TOTAL ANNUAL COST OF OPERATION 0.Excludin'5 Depreciation a
g 9
9 i serw%-..,,_
f^4 :
G 1.a.
ATTACR'-;Elli FOR ITEI: lid.
ESTIMATED ANiiUAL COST OT OPERATING flUCI EAR GENERATIliG UNIT:
Wron 1 FOR THE CALEliDAR YEAR 19g (thousands c,f dollars)
Operation and maintenance expenses Nuciear power generation
~ ha: lear fuel expense (plant factor 50 %)...........$
52,495 29.P23 Other operating expenses.....................
17.432 F.aintenance expenses.......................
o9. 3 so Total nuclear power generation.............
45 Transmission expensest........................
)
A$ninistrative and geneVal expenses 6,600 Property and liab'lity insurance.................
8.611 Other A. 8G. exp ens es.......................
15,211 Total A.&G. expenses....................
114.406 TOTAL 0&M E.XPENSES......................
47,755
~
Depreciation expans e.........................
Taxes other than incone taxes 7,362
_ Property taxes.............,.............
11,602 Other...............................,
16.96c Total taxes other than income taxes...........
68,550 I nccce ta xe s - Fe d e ra l..' <.....................
10,190 I n cecie t a x e s - o t h e r.........................
62,053 Deferred income taxes - net.......,...'.........e..
3,235 _
Investment tax credit adjustments - net................ _
t 234,711 16.17 T )...................
Return (rate of return: _
< $ [559,864 TOTAL ANNUAL COST OF OPERATION e.
O. Excluding Depreciation o
i
~
&r
(
ATTACH",ENT FOR ITER. liO.
1.a.
O t511x^1ro annuit cost Or 08ta^Tir a ><uc' taa ocuta^11"s UNIT:
Byron 1 FOR lHL CALEliDAR YEAR 19_8.6 (thousandsofdollars)
Operation and maintenance expenses fiuclear po,,er generation lo: lear fuel expense (plant factor 50 %)........... $
50,652 Other operating expenses.....................
31.e53 Faintenance expenses.......................
19,001 Total nuclear power generation.............
101,506 J
Transmission expenses?........................
49 Administrative and oenefal expenses Property and liability insurance..................
6,820 Other A.&G. expens es.......................
8.ela Total A.8G. expenses....................
15,635 l
TOTAL D&M EXPENSES.....................,
117.100 Dep,es a tion expens e.........................
e,1m Taxes other than intone taxes Property taxes............................
7,861 Other................................
10.750 Total taxes other than income taxes...........
18,622 I n ecc e ta x e s - Fe d e ra l..,-.....................
70,016 l
I n C0~ie ta x e s = o t h e r.........................
in _ LM
, Deferred income taxes - net...'.......'.....'.......
50.647 Investment tax credit adjustments - net................
3,235
.Re? urn (rate of return:
16.17 %)...................
217,56L 535,980_
TOTAL ANNUAL COST OF OPERATION C. Excluding Depreciation O
em 9
i
\\[
m
~
1nr ATTACK':ENT-FOR ITEM liO.
1.a.
ESTIKATED AtumAL COST OF OPERATIf!G flUCI EAR GEtiERATIl!3
. UNIT:
Byron 1
~ FOR lHE CALEliDAR YEAR 19g
~
(thousandsofdollars) heration an:' naintenance expenses tiuclear po:er eeneration 50 %)........... $ 51, 2 51
^ hu: lear fuel expense (plant factor Other operating expenses..................... _34,719 20,711 FJtintenance expenses.......................
106.6e' Total nuclear power generation.............
~
Tra nsrai s s i o n ex p e n s e s t. '....'............... "....
53 Mministrative and oeneVal expenses 7,056 Property and liability insurance.................
9,265 O t.h er A. &G. e x;) c n s e s.......................
Total A.&G. expenses.................... _ 16. m 123,055 n -
TOTAL D EM EX P E N 5E S.....................
48,477 _,
~
. Depreciation expens e.........................
8,097 Taxes other than income taxes Property taxes..._..........,............... _ 10. OM Other.........
18.oc9 Total. taxes other than income taxes...........
72,372 Inccce taxes - Federil..
- e.....................
10.7ec Inccce ta xes - o the r.........................
39,60 Deferred income taxes - net.......,..."............
3,235 _
Investment tax credit adjustments - net................
16.17_ %)................... pop pp Return,(rate of return: _
- $ _b 7. Mo TOTAL ANNUAL COST OF OPERATION Cluding.DepreCistion 1
l e
1
ir ATTACHMENT FOR ITD; NO.
1.a.
O ESTIMATED ANiiUAL COST OF OPERATING WCl EAR GEliEPATING UNIT: Byron 1 FOR THE CALEliDAR YEAR 1958 (thousandsofdollars)
Operation and maintenance expenses
~ Hucicar power generation hu: lear fuel expense (plant factor 50 %)........... $
52,953 37.ect Other operating expenses.....................
22,579 Maintenance expenses.......................
113.372 Total nuclear power generation.............
Transmission expensest.....'..............."....
58 -
Abinistrative and ceneVal expenses 7,305 Property and liability insurance.................
9,6M Other A.&G. expenses.......................
17,15L Total A.&G. expenses....................
130.59L TOTAL O LM EX P E N S E S.....................
48,887 Depreciation expense.............'............
Taxes other than incone taxes 8.Lo1 Property taxes.....,.................,....
9.3r_
Other................................
17.7c?
Total taxes other than income taxes...........
65,869 Inccce taxes - Federal.. c.....................
9.7FF I ncome t a x es - other.........................
39,6L1 Deferred income taxes - net
...'....,...'.....~.....
3,235 Investment tax credit adjustments - net............... <
188.733 Return (rate of return:
1_6_.17 %)..................-
$[504.45o TOTAL ANWAL COST OF OPERATION C A cluding Depreciation U
e 9
i 9
r*;r
\\
ATTACR'iENT FOR ITU: H0 l
ESTIMATED ANNUAL COST OF OPERAl 1.a.
i UNIT:
3 Byron 1
~' FOR THE cal ENDAR ' YEAR t
~
(thousands of dollars)
~
~
Operation and maintenance ex Nuclear power ceneration penses hxlear fuel expense Other operating expen (plan Maintenance expenses.ses. t factor...... h %).....
s Tota l nuclear........
..... $ 55,896 TransN.ission expensest.
power genera tion 41 250 24,,606 A r.inistrative and cenefal e....'...........
121,7sp Property ed liability
....'.... _ 63 xpenses Other A.&G. expenses.. insurance....
Tota l A. &G. expenses........
TOTAL D&M EXPENSES...........
7 578
.......... ~
.t o,,574 tprecfation expense 18,157 139,967 xes other than incone taxes............'.....
$ rop::rty ta M2r....xes.............
49,334 Total taxes other than incom.................
ce taxes - Federal..
c-e taxes...
8,652 6 66L w taxes - other......................
17,,31 t>
red income taxes net 59,312 Went tax credit adjustment... '....... '..... '.
8,81 6 (rate of return:
s - net..........
39,6L1 16,17 %).......
TOTAL ANNUAL COST OF OPERATION
%pu 175,216 iding preciation
- $ '492,837
\\
1e -
I o
s-
, - - ~ ". _. -
- h. -*
\\
ATTACW:ENT FOR ITU: liO.
1.a.
ESTIMATED ANiiUAL COST OF OPERATING liUCI E R GEliEP.ATiliG Uli!T:
Byron 1 FOR THE CALEliDAR YLAR 193 (thousandsofdollars)
Operation and maintenance expenses Euclear po,eer generation
^ ha:1 ear fuel expense (plant factor 50 %)........... $ 59,226 44,953 Other operating expenses.....................
26.821 Maintenance expenses.......................
131.010 Total nuclear power generation.............
Tra nsraission expenses *.....'...................
fc Aininistrative and ceneVal expenses 7,867 Property and liability insurance.................
11.377.
Other A. 8G. e xpenses.......................
19.2L5 Total A.&G. expenses....................
550,324 TOTAL DEM EXPENSES....................,
.O 49,822
~
Depreciation expense.........................
Taxes other than ince.c taxes A _ 07 't Prop
- Tty taxes.............,..............*
S. VL Oth*T................................
16.c17 Total taxes other than income taxes...........
l 57.650 Inccre taxes - Federal.. c.....................
8,'571 I n ecce t a x e s - oth e r.........................
Deferred income taxes - net.......,...'.....~....;..
34,03?
3,235 Investment tax credit adjustments - net................
161,700 Return (rate of return: 16.17 % )...................
$[482,258 TOTAL ANNUAL COST OF OPERATION 1
O Excluding Depreciation e
e#
e G
~
z.
/
~
o 1.a.
ATTACR'4EtiT FOR ITEM NO.
e
> s
. O tstix^>to ^urmat cost or orta^T1><a imc' t a at><ta^T ><
UNIT:
Byron 2 FOR THE CALEliDAR YfAR 1935 (thousandsofdollars)
Operation and maintenance expenses Nuclear power generation _
50 %)........... $ 56,467
~ hu: lear fuel expense (plant factor 26,7e7 Other operating expenses.....................
15,979 Maintenance expenses.......................
99,233 Total nuclear power generation.............
Transnission expenses?.....'............... "....
41 A r.inistrative and oenefal expenses 5,268 Property and liability insurance....
s. e -7 Other A.&G. exp enses.......................
13.ees Total A.&G. expenses....................
113,159 TOTAL OLM EXPENSES.....................
O' 33,232 Depreciation expense.............'............
Taxes other than incone taxes 3.878
~ Property taxes.............,...............
8,153 Oth e r................................
12,031 Total taxes other than income taxes...........
67.477 Inccee taxes - Federal.. e.
10,030 I n cron t a x e s - o t h e r......................... _
21,858 Deferred income taxes - net.......,...'.........&
p.noo Investment tax credit adjustments - net................
164,863 Return (rate of return:
16.17_%)...................
~
$_ 424,732_
TOTAL ANNUAL COST OF OPERATION e-I O. Excluding Depreciation O
l e
-(yJ. r
/
k ATTACP.ENT FOR ITEM lid.
1.a.
ESTIMATED AfillUAL COST OF OPERATIliG liUCI E R GEliERATIliG UtilT: Byron 2
~ FOR THE CALEliDAR YEAR 19_86 (thousandsofdoliars)
Operation and nintenance expenses huticar power generation _
haclear fuel expense (plant factor 50 %)........... $ 55,052 31,853 Other operating expenses.....................
19,001 Maintenance expenses.......................
Total nuclear power generation.............
105.ov Transmission expensest.....'..............."....
49 Mministrative and aeneVal expenses 4,986 Property and' 11abGity insurance.................
9.307 Other A.&G. exp enses.......................
- 14. m:
Total A.&G. expenses....................
120.17o TOTAL D EM EX P E N S E S......................
33,577 Depreciation expense.............'............
Taxes other than incone taxes 5,081 Property taxes...........................-
7,70 Other................................
12.e25 Total taxes other than income taxes...........
32,113 Inccne taxes - Federal.. c.....................
4,773 I n come t a x e s - o t h e r.........................
Deferred income taxes - net... '....,... '...... '......
57.555 2,082 Investment tax credit adjustments - net..........
Return (rate of return:
- 16. -17 % )...................
, c6_ ccn
$_'419.983 TOTAL ANNUAL COST OF OPERATION 0
luding' Depreciation S
e 0
o;z ATTACP.'iENT FOR ITEM NO.
1.a.
ESTIMATED ANiiUAL COST OF OPERATING liUCI EkR GEliERATIliG O
UNIT:
Byron 2 FOR THE CALEliDAR YEAR 19_8_7
~
(thousands of dollars)
Operation and maintenance expenses Nuclear power generation ha:1 ear fuel expense (plant factor 50 %)........... $
53.149 34,719 Other operating expenses.....................
20,711 Maintenance expenses.......................
los.s70 Total nuclear power generation.............
~
Transmission expenses t.....'............... ".
53 h
Ad..inistrative and ceneVal exoenses_
s 5.108 Property and liabnity insurance.................
9.4xn Other A. 8G. e xp e ns es.......................
16,53E Total A.&G. expenses....................
123.170,
TOTAL O&M EXPENSES.....................
-p Dep,J ation exp ens [e......................... _ 33,954
~
Taxes other than inco.e taxes 5,234 Property taxes.............,...............
7,051 Oth:r................................
12.285 Total taxes other than income taxes...........
34,693 I n com e ta x e s - Fe d e r a l.. <.....................
5,157 I n car.e t a x e s - o th e r.........................
Deferred income taxes - net...'....,... '......'......
47,077 2.0P9 Investment tax credit adjustments - net................
142,465 Return (rate of return:
16.17 _%)...................
TOTAL ANtiUAL COST OF OPERATION
$[400,883
- 0. Excluding Depreciation G
D 9
-(f h1 THCY.'iENT FOR 1IEM HD.
1.a.
O ESTIMATED ANNUAL COST OF OPERATING NUCI E R GENERATING ig UNIT:
Byron 2 FOR THE CALENDAR YEAR 1988 (thousandsofdollars)
~
Operation and maintenance expenses
~ Euclear power generation ha: lear fuel expense (plant factor so f)........... $
54,026 37, ELL Other operating expenses.....................
22,575 Maintenance expenses.......................
114.4Ls Total nuclear power generation.............
~
Transmission expenses?...................."....
58
~
_Adninistrative and gene $al expenses 5,238 Property and liabMity insurance.................
o.oco Other A. &G. expenses.......................
15.277-Total A.8G. expenses....................
129,691 TOTAL O Di EX P EN S E S.....................
R 364 Depreciation expense.........................
i Taxes other than income taxes 5,391
~ Property taxes.............,...............
6,c3c Other................................
11 E2c Total taxes other than income taxes...........
34,990 I
Inccce taxes - Federal..,.....................
4,962 In ccce tax es - other.........................
Deferred income taxes - net...'....,...'............
39,872 2,082 f Investment tax credit adjustrients - net................
16.17 % )................... _ 130.001 Return (rate of return: _
$ '387,869 l
TOTAL ANNUAL COST OF OPERATION O. Excluding Depreciation O
D 0
e
., x 3
\\
ATTACK 9ENT FOR ITEM NO.
1.a.
ESTIMATED ANiWAL COST OF OPERATING NUCIEIR CENERATING UNIT: Byron 2 FOR THE CALEliDAR YEAR 1983, (thousandsofdollars)
Operation and maintenance expenses
~ Euclear power generation
~ hxlear fuel expense (plant factor 50 %)........... $
56,060 41,250 Other operating expenses.....................
24,606 Maintenance expenses.......................
121,916 Total nuclear power generation.............
Transmission expenses ?.....'............... "....
63 _ '
AdIinistrative and cenefal expenses s.377 Property and liabnity insurance.................
10.58c Other A.&G. expenses.......................
15,965 Total A.&G. expenses....................
137,944 TOTAL O&.M EXPENSES.....................
34,811 Dep ation expense..............'............
Taxes other than incone taxes 5,552 Property taxes............................
5.692 Other................................
Total taxes other than income taxes...........
11.435 35,853 l I nccrne ta x es - Fe d e ral.. <-.....................
5,329 Income ta x es - oth e r.........................
Deferred income taxes - net...'.......".........&
32,666 2,082 Investment tax credit adjustments - net................
118,ees Return (rate of return:
16.17 % )...................
TOTAL ANNUAL COST OF OPERATION
' $ _ ' 379,008 0 Excluding Depreciation D
9
z cy
\\
ATTACR'iENT FOR ITEM NO.
1.a.
O ESTIMATED ANiiUAL COST OF OPEPATIH3 NUCI EIR GENERATING UNIT: Byron 2 FOR THE CALENDAR YEAR 19,gg (thousandsofdollars)
~
Operation and maintenance expenses Nuclear power eeneration ha:1 ear fuel expense (plant fattor 50 %)........... $ 59,256 Other operating expenses.....................
44,963 Maintenance expenses.......................
26,821 Total nuclear power generation............. _131.06n
~
Tra nsmission expens es ?.....'............... "....
69 Administrative and ceneVal expenses Property and liability insurance.................
5,526 Other A. 8G. expens es.......................
11.391 Total A.&G. expenses.................... _ 16.cov TOTAL O&M EXPENSES.....................
149.016
~
35,2ee Depres a ti n ex, ens e.........................
Taxes other than incone taxes 5,719 Property taxes............................
9,367 Other..................,.............
Total taxes other than income taxes...........
11.106 In com e ta x e s - Fe d e ra l.. <-.
37,273 Incme taxes - other.........................
5.540 Deferred in ome taxes - net... '....,... '............
25,461 Investment tax credit adjustments - net................
2,082 Return (rate of return:
16.17 %)................... Ice,en,
$ 373,628 TOTAL ANNUAL COST OF OPERATION
- 0. Excluding; Depreciation
~
O
~
o l
g 0
\\
ATTACK'iEtiT FOR ITEM liO.
1.a.
ESTIMATED ANiiUAL COST OF OPERATIliG IIUCI EIR GEtiERATiliG UlilT:
Byron 2 FOR THE CALEtiDAR YEAR 1991 (thousandsofdollars)
~
Operation and maintenance expenses Nuclear power generation hu: lear fuel expense (plant factor 50 %)........... $
62,e61 49.000 Other operating expenses.....................
29.235 Maintenance expenses.......................
Total nuclear power generation.............
141.105 75 Transmission expensest........................
Akinistrative and oenefal exoenses 5,686 Property and liab'lity insurance.................
12,255 Other A.&G. expenses.......................
17.ca!
Total A.8G. expenses....................
i 1
l TOTAL 0&M EXPENSES......................
a no, m 35,830_,
, tion expense.........................
Deprel:
a Taxes other than intone taxes 5,691 Property taxes.............,...............
4.oL7 Other................................
Total taxes other than income taxes...........
10,e3e 39.258 In coc:e ta xe s - Fe d e ral..,-.....................
5,836 I n ccx.e t a x es - o th e r.........................
Deferred income taxes - net................'......
18,256 2,082 Investment tax credit adjustments - net................
99,971 16.17 5 )...............,....
Return (rate of return: __
$ ' 371.192 TOTAL ANh'UAL COST OF OPERATION
- o. Excluding Depreciation
~
O
~
m
(
.cyz ATTACK,ENT FOR ITEM HO.
1.a.
ESTIMATED ANNUAL COST OF OPERATING IIUCI E R GEtiERATIliG O
UNIT:
Byron 1 FOR THE CALEliDAR YEAR 19_84 (thousandsofdollars)
Operation and maintenance expenses
- tioclear power generation 60 %)........... $ 64,580
~ huclear fuel expense (plant factor 24.576 Other operating expenses................
,_ 14,660 Maintenance expenses.......................
103.M 6 Total nuclear power generation......._......
~
Transmission expensest.....'..............."....
38 Administrative and geneVal expenses _
~
6,789 Property and liability insurance.................
9,015 Other A.&G. expenses...
1s.pnt Total A.&G. expenses....................
,,o Acc TOTAL OfJi EXP ENSES.....................
0 47,43s
- 0,,eciati.n expense.........................
Taxes other than intone taxes 5.895 Property taxes............................
12,179 Other................................
16,07u Total taxes other than income taxes...........
103,479 Income taxes - Federal.. c.....................
25,382 I n tcc.e t a x e s - o th e r.........................
29,435 Deferred income taxes - net...'.......'............_
3,235_
Investment tax credit adjustments - net................ _
246,412 Return (rate of return:
16.17 % )................... _
582.113-TOTAL ANNUAL COST OF DPERATION
- 0. Excluding Depreciation e
e O
o O
e 0
e
~,-
..'Z 1.a.
ATTACH".ENT FOR ITEM NO.
ESTIMATED ANNUAL COST OT OPERATING NUCIEAR GENERATING UNIT:
Wron 1
^ FOR THE CA!.ENDAR YEAR 19 g (thousandsofdollars) l
)
Operation and maintenance expenses
- Nuciear power generation 60 %)........... $ 62,994
^ ha: lear feel expense (plant factor 29.pp3 Other operating expenses.....................
17.432 F.aintenance expenses.......................
109.6Lc Total nuclear power generation.............
45 Transmission expensest........................
Ahministrative and genefal expenses 6,600 _
Property and liability insurance.................
9.52P Other A. &G. expens es.......................
16,122 Total A.&G. expenses....................
125,816 TOTAL D&M EXPENSES......................
47,755
~
reciation expense.........................
7,362 Taxes other than income taxes Property taxes............................
11,602 Other................................
18,964 Total taxes other than income taxes...........
68,550 I nccee ta xe s - Fe d e r a l.. <-............... ~......
10,190 I n ca a ta x es - other.........................
62,053 Deferred income taxes - net 3,235
, Investment tax credit adjustments - net................
234,712 16.17 T )...................
Return (rate of return:
$ _ '571. 22!4_
TOTAL ANNUAL COST OF OPERATION O. Excluding Depreciation en O
4 r
1.a.
ATTACW;ENT FOR ITU; NO.
LSTIKATED ANNUAL COST OF OPERATING fiUCI EIR GENEP.ATING UNIT:
Byron 1 1
FOR THE CALEliDAR YEAR 19 86 (thousandsofdollars)
Operation and maintenance expenses h'ucietr power generation
~ ha:1 ear f uel expense (plant factor 60 %)........... $
60,782__
31.853 _
Other operating expenses.....................
19,001 Maintenance expenses.......................
111. m Total nuclear power generation.............
49 Transmission expenses t.....'...................
Administrative and oeneVal exoenses 6,820 Property and liability insurance.................
9.6cn Other A. 8G. expens es.......................
16,515 Total A.&G. expenses....................
TOTAL OfJi EXPENSES............... [.....
128,200
,.O 48,100_,
~
Depreciation expense.........................
Taxes other than incone taxes 7,861 Property taxes.............,..............
20.760 Other................................
18.621 Total taxes other than income taxes...........
70,016 l
l Income ta x e s - Fe d e ra l.. <-.....................
7 n an, I ntcce t a x e s - o t h e r.... ~.....................
50,847 Deferred income taxes - net.......,...'.........e..
3,235 Investment tax credit adjustments - net................
217,564 16.17 %)...................
Return (rateofreturn: _
$ ' 546,990 TOTAL ANNUAL COST OF OPERATION
- 0. Excluding Depreciation O
e 8
0
~,.
e
' _~
\\
ATTACR'!ENT FOR ITU: liO.
1.a.
ESTIMATED ANiiUAL COST OF OPERATIliG IIUCI EAR GENERATIl!G UlilT:
Byron 1 FOR lHE CALEliDAR YEAR 1987 (thousandsofdollars)
Operation and maintenance expenses
~ Nuclear power generation haclear fuel expense (plant fattor 60 %)........... $ 61,502 34,719 Other opera ting expenses.....................
20,711 Meintenance expenses.......................
Total nuclear power generation.............
116.oxo
~
Transmission expensest.....'...................
53 Administrative and geneva 1 expenses 7,056 Property and liability insurance.................
10,155 O ther A. &G. expenses.......................
Total A.8G. expenses....................-
1 7. 21, 134,196 TOTAL O&M EXPENSES.....................
48.477 Depreciation expense.............'.............
Taxes other then intone taxes 8,097 Property taxes............................
- 10. om Other................................
Total taxes other than income taxes...........
18.oos 72,372 I n ccne ta x e s - Fe d e r a l.. <.....................
10.759 I ntcce ta x es - other.........................
Deferred income taxes - net...'.......'............
39,641 3,235 Investment tax credit adjustments - net................
Return (rateofreturn:
16.17 % )................... p o p. p x o
~
$ 529,009 TOTAL ANNUAL COST OF OPERATION O cluding Depreciation g
4 h
~
=.
- m..
., Q '
^
ATTACR'iENT FOR ITU: HD.
1.a.
ESTIMATED ANNUAL COST OF OPERATING NUCl EkR GENERATING UNIT: Byron 1 FOR 1HE CALEtiDAR YEAR 19_88 (thousandsofdollars)
Operation and maintenance expenses Nutiear power generation hxlear fuel expense (plant factor 60' %)........... $
63,543 37,844 Other operating expenses.....................
22,575 Maintenance expenses.......................
123.962 Total nuclear power generation.............
~
Tra nsmis sion exp e ns e s t.....'............... "....
58 _
Ad inistrative and ceneVal expenses
~
7,30s Property and liabGity insurance.................
10,766 Other A.8G. expenses.......................
18.07L Total A.&G. expenses...................-. _
142.004 TOTAL D &M EX P E N S E S.....................
.O
~
48,887 l
Depreciation expense.........................
Taxes other than incone taxes 8.401 Property taxes............................
9.361 Other................................
17.7cp Total taxes other than income taxes...........
65,869 I ncome ta xe s - Fe d e r a l.. <-.....................
9.7EF I ncase t a x es - other.........................
39,661 Deferred income taxes - net.......,...'............_
3,235_
Investment tax credit adjustments - net................
188 733-Return (rate of return: _,J_,6. 17 %)..................-
$ ' 515.oAit TOTAL ANNUAL COST OF OPERATION
- 0. Excluding Depreciation s
9 O
e 9
, ~ ~,,
w n
n
.,- V r 1.a.
ATTACH'iENT FOR ITEX NO.
m)
E.5TIKATED ANNUAL COST OF OPERATING NUCI EAR GENERATING UNIT:
Byron 1
~ FOR THE CALDiDAR YEAR 1969 (thousandsofdollars)
Operation and maintenance expenses _
60 %)...........$
67,075 tiuclear power ceneration
~ huelear fuel expense (plant factor 41,250 __
Other operating expenses.....................
24,606 Maintenance expenses.......................
132,933 _
L Total nuclear power generation.............
63 Transmission expensest.....'............... "....
/&inistrative and cenehl expenses t
7,578 _
Preperty and liability insurance.................
11,545 Other A.&G. expenses.......................
19,123 Total A.&G. expenses....................
I w,,,
TOT AL 0 &M EXP E N S E S.....................
49,334_,
Depreciation expense.............'............
Taxes other than intone taxes 8,652
_ Property taxes.............,...............
8,664 Other................................
17,316 Total taxes other than income taxes...........
59,312 Inccce taxes - Federal.. c.
8,616 Income ta x es - othe r.........................
39,6t.1
...'....,...'.........e.._
Deferred income taxes - net
- 3. ns _
Investment tax credit adjust 7nents - net................
175,216 Return (rate of return: _16.17 %)...................
$_'504,987 TOTAL ANNUAL COST OF OPERATION cluding Depreciation
.e*
e e
D
O_
r
., v.
\\
~
ATTACH".ENT FOR ITU: NO.
1.a.
ESTIMATED ANNUAL COST OF OPERATING NUCI EkR GENERATING UHIT:
Byron 1 FOR THE cal.ENDAR YLAR 1990 (thousandsofdollars)
Operation and maintenance expenses Nuclear po,<er oeneration
~ hu: lear fuel expense (plant fattor 60%)........... $
71,072 Other operating expenses.....................
44,9E5 Maintenance expenses.......................
26.621 Total nuclear power generation.............
142.e56,
~
~
Transmission expenses?.....'...................
go
)
Administrative and oeneVal expenses
~
Property and liabnity insurance.................
7,867 Other A.8G. e xpens es.......................
12.407 Total A.&G. expenses......
20,27c
. O.
TOTAL O&M EXPENSES.....................
163.100
~
Depreciation expense.........................
49.822 Taxes other than income taxes Proptrty taxes.............,.. a P ; o1 ?
Oth27................................
R.nnL Total taxes other than income taxes...........
16.917 57.6so Inccr:e taxes - Federal.. c.
Income taxes - other.........................
8,571 Deferred income taxes - net.......,...'............
34,030 t
Investment tax credit adjustments - net................
3,235 l
Return (rate of return: 16.17 % )...................
161,700
$ '495.133 TOTAL ANNUAL COST OF OPERATION l C.
uding Depreciation 1
O
i-kl g-r ATTACH'iENT FOR ITEf', liO.
1.a.
ESTIMATED AN!iUAL COST OF OPERATIliG NUCIE R GENERATIliG UNIT:
Byron 2 FOR THE CALEliDAR YEAR 1565
~
(thousandsofdollars)
Operation and maintenance expenses Nuclear power generation
~ haclear fuel expense (plant factor 60 %)........... $ 67. 76n 26,767 Other operating expenses.....................
15,979 F.aintenance expenses.......................
n o. c pc Total nuclear power generation.............
~
Tra nsmi s s ion e _xp e ns e s t.....'............... "....
41
/binistrative and ceneVal expenses 5,269 Property and liabnity insurance.................
9.596 Other A.8G. expenses.......................
11.,866 Total A.&G. expenses.....................
125,433 TOTAL D&M EXPENSES....................,
..o 33,232 _.
Depreciation expense.........................
Taxes other than incone taxes 3,878 Property taxes............................
8,153 Other................................
12,031 Total taxes other than income taxes...........
67.477 Inccce taxes - Federal.. c.....................
10,030 Jnctce ta xes - other.........................
Deferred income taxes - net... '....,... '............
21,858 p.nop Investment tax credit adjustments - net................
Return (rate of return:
16.17 %)...............,....
164,863_
TOTAL ANNUAL COST OF OPERATION
$_'437,006
- 0. Excluding Depreciation o
e 8
1
~
o,
\\,.-
ATTACP.'-lENT FOR ITU: liO.
1.a.
ESTIl%TED AfiliUAL COST OF OPERATING NUCI E4R GEliERATING UNIT: Byron 2 FOR THE CALEliDAR YEAR 1986 (thousands of dollars)
Operation and maintenan:e expenses
~ Nucitar power generation
~ haclear fuel expense (plant factor 60 %)........... $ 66,063 31,853 Other operating expenses..................... _19,001 Maintenance expenses.......................
116.o17 Total nuclear power generation.............
Transraission expensest.....'............... "....
49 Air.inistrative and ceneVal expenses 4,986 Property and liability insurance.................
10,153 Other A.8G. expenses.......................
- 15. no Total A.&G. expenses....................
132,105 TOTAL 0&M EXPENSES.....................
33,577
~
Deprec,iation expense.........................
Taxes other than incone taxes 5,081
~ Property taxes.............,............. e 7,745 Other................................
12.e26 Total taxes other than income taxes...........
32,113 inccce taxes - Federal.. c.....................
4,773 I n ccce t a x e s - o the r.........................
Deferred income taxes - net...'....,...'............
57.885 2,082 Investment tax credit adjustments - net................
Return (rate of return:
16.17 5 )...............,....
1 c t e c g._,
TOTAL ANNUAL COST OF OPERATION
$[431.950 _
- 0. Excluding Depreciation
~
e 0
e O
9 s
g" 3
o ATTACK"EtiT FOR ITEl* liO.
1.a.
f ESTIMATED ANiiUAL COST OF OPERATIliG fiUCI EIR GEliERATiliG
~
N UNIT:
Byron 2 FOR THE CALEliDAR YEAR 19 87
~
~
(thousandsofdollars)
Operation and rnaintenance expenses I
tiuclear power ceneration haclear fuel expense (plant factor 60 %)...........$
63,779 34,719 Other operating expenses.....................
20,711 Taintenance expenses.......................
Total nuclear power generation.............
119.90o
~
Transmission expenses *.....'............... "....
53 Ab.inistrative and o-neval expenses 5.108 Property and liability insurance.................
10.353 Other A. &G. exp ens es.......................
15,4 f.2 Total A.&G. expenses....................
TOTAL DEM EXPEN5ES....................',
134,723 De intion expense.............'............
33,954 Taxes other than incone taxes 5.234 Property taxes............................
7,051 Other................................
Total taxes other than income taxes...........
12.285 34,693 I n c cc e ta x e s - Fe d e r a l.. <-......................
5,157 I
I n coc;e ta x e s - o th e r.........................
Deferred income taxes - net... '....,... '...... '......
47,077 2.0a>
Investnent tax credit adjustments - net................
Ret. urn (rate of return:
16.17 %)...................
142,465
- $ ' 412,436 TOTAL ANNUAL COST OF OPERATION 0 Excluding Depreciation V
a g
e e
m.
c
~
r ATTACK';ENT FOR ITEl' HO.
1.a.
O ESTIMATED ANINAL COST OF OPERATING NUCIEiR GEliERAT1HG UNIT:
Byron 2 FOR THE CALENDAR YEAR 19_88 (thousandsofdollars)
Operation and maintenance expenses Nuclear power generation
~ hu: lear fuel expense (plant factor 60 % )........... $
64, e.31 37,844 Other operating expenses.....................
22,575 Maintenance expenses.......................
125,250-Total nuclear power generation.............
~
Transmission expenses?.....'..............."....
58 Ab.inistrative and geneva 1 expenses 5,238 Property and liability insurance.................
10.877 Other A.8G. expenses.......................
16,115 Total A.8G. expenses....................
it1. a n TOTAL O&M EXPENSES.....................
34,364 oepres atsen expense.........................
Taxes other than incone taxes 5,391 Property taxes............................
6,43s Other................................
11 E25 Total taxes other than income taxes...........
~
34,990 I n ccc e ta x e s - Fe d e r a l.. <.....................
4,962 I n tcce t a x e s - oth er.........................
Deferred income taxes - net..........'.........;.._
39,872 2,082 Investment tax credit adjustments - net................
Return (rate of return:
16.17 % )...................
130.0o,3_
~
399.611 TOTAL ANNUAL COST OF OPERATION
- 0. Excluding Depreciation D
e
1 Q=
\\
ATTACK'iENT FOR ITEM NO.
1.a.
ESTIMATED ANNUAL COST OF OPERATING NUCIEIR GEliERATING UNIT: Byron 2 FOR THE CALENDAR YEAR 17.8._9
~
(thousandsofdollars)
Operation and maintenance expenses Nuclear power generation ha:1 ear fuel expense (plant factor 60'
%)...........$
67.277 Other operating expenses......................
41,250 Maintenance expens es.......................
24.606
~
Total nuclear power generation.............
133.128
~
~
Transmission expensest.....'...................
63 Akinistrative and genefal expenses Property and liability insurance.................
s.377 Other A. 8G. expens es...............
11.569 Total A.&G. expenses....................
16,93o
~
TOTAL 001 EXPENSES.....................
150,130
-O.~
~
34,811 Depreciation expense.........................
Taxes other than incone taxes 5,552 Property taxes.............,...............
Oth:r................................
5.6e3 Total taxes other than income taxes...........
11,435 35,853 Inccce taxes - Federal.. c.....................
Inccce ta xes - o th e r.........................
5,329 Deferred income taxes - net...'.......'............
32,666 Investment tax credit adjustments - net................
2,082 Return (rate of return:, 16.17 % )...................
118.ses TOTAL ANNUAL COST OF OPERATION
$ _ ' 391.194
- 0. Excluding Depreciation
~
f
~
ATTACEENT FOR ITU: HD.
1.a.
ESTIKATED ANNUAL COST OF OPERATING NUCI E R GENERATING O'
UNIT: Byron 2 FOR THE CALENDAR YEAR 19,20 (thousandsofdollars)
Operation and maintenance expenses Euclear power ceneration Axlear fuel expense (plant factor 60 %)........... $ 71,107 44,963 Other operating expenses.....................
26,621 Faintenance expenses.......................
142.e92 Total nuclear power generation.............
~
~
69 9
Transmission expensest.....'...................
Adhinistrative and cenefal expenses
~
5.526 Property and liabnity insurance.................
12,410 Other A. 8G. expenses.......................
- 17. cv Total A.&G. expenses....................
160,896 TOTAL OL". EXPENSES.....................
Depreciation expense.............'............ _ 35,299 Taxes other than incone taxes 5,719 Property taxes............................
D,fV Other..................'..............
- 11. fos Total taxes other than income taxes...........
37,273 Income taxes - Federal.. c.....................
5.560 Inca.e ta xes - other........................ -
, Deferred income taxes - net...'....,... '......... :
25,461 2,082 Investment tax credit adjustments - net................
R:! turn (rate of return:
16.17 _5)................... los.ec,
$ ksR nna TOTAL ANNUAL COST OF OPERATION
- 0. Excluding Depreciation 9
D 4
h,
(...
Q^
ATTACH".ENT FOR ITEM TiO.
1.a.
ESTIMATED ANNUAL COST OF OPERATING NUCI EIR GEtiERATING UNIT:
Byron 2
~ FOR THE CALEfiDAR YEAR 1991 (thousandsofdollars)
~
Operation and maintenance expenses Nuclear power generation 60 %)........'... $
75,434
~ hxlear fuel expense (plant factor 49.000 Other operating expenses....,.................
29.235 Maintenance expenses.......................
153. 67E Total nuclear power generation.............
75 Transraission expens es?........................
Mministrative and ceneVal expenses 5,686 Property and liabnity insurance.................
13.347 Other A.8G. exp ens es.......................
19.033 Total A.&G. expenses......
TOTAL DEM EXPENSES...................'... 172.786 35,830 Deptvc ation expens e.............'............
Taxes other than incone taxes 5,891 Property taxes............................
4.0L7 Othtr................................
10,636 Total taxes other 'han income taxes...........
39.258 In come ta xes - Fe d e r al..,-.....................
5,836 I n come t a x e s - o th e r.........................
18,256 Deferred income taxes - net.......,...'......"... &
~
2,082
' Investment tax credit adjustments - net................
99,971 Return (rate of return:
16.17 % )...................
$_"384.857 TOTAL ANNUAL COST OF OPERATION
- 0. Excluding Depreciation
~
~
O
~
e en e
9
/
. O; r 1.a.
ADACH'iENT FOR ITEP. HO.
r ESTIMATED ANNUAL COST OF OPERATING NUCI E4R GENEPATING b^
UNIT:
Byron 1 FOR THE CALENDAR YEAR 19 84 (thousands of dollars)
Operation and maintenance expenses
~ Euclear power generation _
~hu: lear fuel expense (plant factor 70 %)........... $
75,363 24,576 Other operating expenses.....................
14,660 Maintenance expenses.......................
114. wo Total nuclear power generation.............
3g
~
Transmission expensest........................
M:inistrative and gene $al exoenses 6,789 Property and liability insurance.................
9,949 Other A.&G. expenses.......................
16,73e Trtal A.&G. expenses....................
131.355 TOTAL DEM EXPENSES.....................
47,438 ciation expense.............'............
Dep Taxes other than incone taxes 5.895
~ Property taxes............................-
12,17=
Other................................
16,074 Total taxes other than income taxes...........
1 103,479 I n ccc e ta x e s - Fe d e r al.. <.....................
15,382 Intcce ta x es - oth er......................... _
28,435 Deferred income taxes - net 3,235 Investment tax credit adjustinents - net................
246,412 Return (rate of return:
16.17_% )...................
~ 93.810 5
TOTAL ANNUAL COST OF OPERATION O Excluding Depreciation o
D 0
r ATTACK"ENT FOR ITEM liO.
1.a.
ESTIMATED ANiiUAL COST OF OPERATlHG fiUCI EAR GEliERATlHG UNIT:
Byron 1
^
FOR ItiE CALEliDAR YEAR 19g (thousandsofdollars)
Operation and maintenance expenses
~ tiuciear poser generation
%)........... $ 73,493
^ tiv: lear fuel expense (plant factor 70 29.??3 Other operating expenses.....................
17.632 Maintenance expenses.......................
1 po. u r, Total nuclear power generation.............
Transmission expensest....................'....
45 _'
Administrative and geneVal expenses 6,600 Property and liability insurance.................
10,433 Other A. &G. exp ens es.......................
17.03; Total A.&G. expenses......
TOTAL 0&M EXPENSES............'......... _137.pp6 Depreciation expense......................... _ 47,755 _,
~
Taxes other than intone taxes 7,362 Property taxes............................
11,602_
Other................................
18,96L Total taxes other than income taxes...........
68,550 I ncome ta x e s - Fe d e ral.. <-.....................
10,190 I n ca,e t a x e s - o t h e r.........................
62,053 Deferred income taxes - net..........'.........&
3,235 _
Investment tax credit adjustments - net................
234,711__
Return (rate of return:
16.17 1)...................
582,686 TOTAL ANNUAL COST OF OPERATION Cluding Depreciation O
o O
e D
8
ir ATTACH'iENT FOR ITEM NO. _1.a.
~
O ESTIMATED ANNUAL COST OF DPERATING NUCIEAR GENERATING UNIT:
Byron 1 FOR THE CALEliDAR YLAR 19_@,6 (thousandsofdollars)
Operation and maintenance expenses
~ Nuclear power eeneration 70 % )........... $
70,912
~ ha:1 ear fuel expense (plant fattor 31.853 Other operating expenses.....................
19,001 Maintenance expenses.......................
121.766 Total nuclear power generation.............
49
..Transmission expensest.....'...................
Administrative and cenefal expenses 6,820 Property and liabGity insurance.................
10,57h Other A.&G. expenses.......................
17,3%
Total A.&G. expenses....................
139.pne G-TOTAL ODI EXPENSES.....................
U 48,100 Depreciation expense.............'............
Taxes other than intone taxes
^
7,861
.Froperty taxes.............,...............
10.767-Other................................
16.622 Total taxes other than income taxes...........
70,016 Income taxes - Federal.. c.....................
'n tm I nccce t a x e s - o th e r......................... _
50,647 Deferred income taxes - net.......,............;..
3,235 Investment tax credit adjustments - net................
217,56L Return (rate of return:
16.17_%)...................
$[557.909-TOTAL ANNUAL COST OF OPERATION 0^ cluding Depreciation U
.e#
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-.____r,
,_~
(.
j r
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\\
1.a.
[
' ATT ACH".Etti FOR ITER. liO.
\\
i ESTIMATED AMMAL COST OF OPERATIt!G 10Cl EAR GEtiERAT
' UtilT:
Byron 1
~
FOR THE CALEliDAR YEAR 19_87 (thousands of dollars)
Operation and maintenance expenses liuc-lear po,eer generation 70 %)........... $ 71,752_
~ haclear fuel expense (plant factor s
34.719 Other operating expenses.....................
20,711 Maintenance expenses.......................
127.182 Tota? -nuclear power generation.............
53 _'
Transciission expensest.................... ".... _
~
?-
Administrative and cenefal expenses 7,056 Property and liab'11ty insurance.................
11,065 Other A. 8G. expens es.......................
_7n.,m Total A.&G. expenses....................
145, pc TOTAL O!.M. EXPENSES...................,,
O' 48.477 _,
-~
~
Depret,iation expense......................... _
Taxes other than income taxes ^
8,097 Property taxes............................
- 10. om Other................................
16.006 1
~
Total taxes other than income taxes...........
72.372 -
I n c ec e ta x e s - Fe d e r al.. <-.......................
10.789 I nccce t a x e s - o t h e r......................... __ 39,6td
.......,...'.........e..
Deferred income taxes - net 3.235 _
l Investment tax credit _ adjustments - net................ _
16.17 J)...............,.... pop _mp p
Return,(rate of return: _
<$ '540,149 __
TOTAL ANh'dAL COST OF OPERATION I
Excluding Depreciation C
e O
0 e
.m,
l Q
..GE7 y
ATTACK'iENT FOR 1 TEM lid.
1.a.
O ESTIKATED ANiiUAt. COST OF OPERATING NUCI EIR GENERATING UNIT: Byron 1 FOR THE CALEliDAR YEAR 19_88._
(thousands of dollars)
Operation and maintenance expenses
~ fiuciear power generation
~ hu: lear fuel expense (plant factor 70 %)...........$
74.13L 37.6LL Other operating expens es.....................
22,575 Maintenance expenses.......................
134.ssa Total nuclear power generation.............
5e [
~
Transmission expensest.....'...................
/N.inistrative and geneva 1 expenses
~
7,30s Property and liabnity insurance.................
11.685 Other A.&G. expenses.......................
18.90s Total A.&G. expenses....................
153.604 TOTAL DLM EXPEN5ES.....................
48,887 Depreciation expense.............'............
Taxes other than incone taxes e.Lol
~ Property taxes..........................
9.361 Other................................
17.7L2 Total taxes other than income taxes...........
65,849 Income taxes - Federal.. c.....................
o.7e?
l Inccce taxes - other.........................
Deferred income taxes - net...'.......'............
39,661 3.235 Investment tax credit adjustments - net................
188.733 Return (rateofreturn:
16.17 %)...................
$ '527.L7o TOTAL ANNUAL COST OF OPERATION e.
O S cluding Depreciation
,e#
e 9
e D
1-
^
'..h *
.y 1.a.
ATTACH'iEliT FOR ITEM fiO.
EST! MATED ANiiUAL COST OF OPERATIliG fiUCI EAR GEtiEPAT1 sJ UtilT:
Byron 1
~ FOR lHE CALEliDAR YEAR 19_89 (thousandsofdollars)
Operation and maintenance expenses iuciear poier eeneration 70 %)........... $ 78,255 _
t hu: lear fuel expense (plant factor
~ 41.250 Other operating expenses.....................
24,606 Maintenance expenses.......................
144.In Total nuclear power generation.............
63 Transmission expensest.....'..............."....
J Administrative and aeneVal expenses 7,578 Property and liab811ty insurance.................
12,515 Other A.&G. expens es....................... _,20.003 Total A.&G. expenses...................~.
164.267_
, TOTAL O&M EXPEN5ES.....................
49,334 _,
~
Depreciation expense.........................
8,652 Taxes other than incone taxes Property taxes............................
8,664 _
Other................................
17,316 Total taxes other than income taxes...........
59,312 I n cczne ta x e s - Fe d e r al..,-.....................
8,816 I n tcce t a x es - oth e r......................,,..
39,661
..........'.........e.-
Deferred income taxes = net
- 3. 9%
Investment tax credit adjustments - net................
175,216 16.17 % )...................
Return (rate of return:
$ [ 517.137; TOTAL AN;TJAL COST OF OPERATION cluding Depreciation o
e e
o 8
e D
--I ir ATTAtmENT FOR ITEP. liO.,,1.a.
ESTIMATED AtiliUAL COST OF OPERATIliG ftUCI E R GEliERAT!!G UtilT:
Byron 1 FOR THE CALEliDAR YEAR 19,90 (thousandsofdollars)
Operation and maintenance expenses Nuclear po,eer generation
~ huclear fuel expense (plant factor 70 % )........... $ 82, 917 44,963 Other operating expenses.....................
26,823 T.aintenance expenses.......................
1 st. ?m Total nuclear power generation.............
Ao Transmission expenses ?.....'...................
1 Airinistrative and geneva 1 expenses 7,867 Property and liability insurance.................
13.43E Other A.&G. exp ens es.......................
21, E Total A.5G. expenses....................
176.07?
TOTAL Oldi EXPENSES.....................
49,822_,
~
eti a tion expens e.........................
Taxes other than incone taxes A 01 A Property taxes.............,...............
- 8. OnL _
Dth!T................................
16.c17 Total taxes other than income taxes...........
57.6so Intcce taxes - Federal.. c.....................
8,571 I n cccie t a x e s - o th e r.........................
34,030 Deferred income taxes - net..........'.........;.,_
3,235 Investment tax credit adjustments - net................
161,700__
Return (rate of return: 16.17 %)...................
508.006 TOTAL ANNUAL COST OF OPERATION
- 0. Excluding Depreciation O
O e
9 e
G l
~
~
s.". ; z 1.a.
ATTACKMENT FOR ITEM fiO.
ESTIMATED AfuiUAL COST OF OPERATING hTCl EAR GENEPATING UlilT:
Byron 2 I
~ FOR THE CALEHDAR YEAR 1935
)
~~~
(thousandsofdollars)
Operation and maintenance expenses
~ fiuclear power generation
%)........... $ 79,053
~huclear fuel expense (plant factor 70 26,787 Other operating expenses.....................
15,979 Maintenance expenses.......................
121.elo Total nuclear power generation.............
41
..Transmission expensest.....'...................
15ministrative and ceneVal expenses 5,768 Property and liabnity insurance.................
10.578 Other A.8G. expenses........................
15,646 Total A.&G. expenses....................
~
~
137,706 TOTAL O&M EXPENSES.....................
33,232
.-Dev,i a tion expens e.............'............
Taxes other than income taxes _
3,678
_ Property taxes............................
8,153 Other................................
12,031 Total taxes other than income taxes...........
67.477 Inecce taxes - Federal.. c.
10,030 __
Inctce taxes - other......................... _
21,858
. Deferred income taxes - net...'....,...'......'... &
2.007 Investnent tax credit adjustments - net................ _
164,863_
16,17 %)...................
Return (rate of return: _
~
$__449,279 TOTAL ANhTAL COST OF OPERATION
- 0. Excluding Depreciation 5
o s
D e
1
e
,/
r V
ATTACR'iENT FOR ITEM lid.
1.a.
ESTIMATED ANNUAL COST OF OPERATIliG ilVClE R GENERATIliG Os UNIT: Byron 2 FOR THE CALEliDAR YEAR 19_86 (thousandsofdollars) t Operation and maintenance expenses
~ tiuclear power generation 70 %)........... $ 77,073 ha: lear fuel expense (plant factor 31,853 Other operating expenses.....................
19,001 Maintenance expenses.......................
127.o97 Total nuclear power generation.............
~
~
49
~
Tra nsrai s s i o n ex p e ns e s t........................ _
Administrative and ceneVal exoenses 4,986 Property and liability insurance.................
11,109 Other A.&G. expenses.......................
16,095 Total A.&G. expenses....................
144,071 TOTAL O&M EXPENSES.....................,
33,577
~
Depr a ation expense.........................
Taxes other than income taxes 5,081___
Property taxes.............,...............
7,745 Other................................
12.626 Total taxes other than income taxes...........
~
32,113 Inctee taxes - Federal.. c.....................
4,773 I n coac t a xe s - o th e r.........................
Deferred income taxes - net.......,...'.........e.._
57.865
~
2,082 Investment tax credit adjustments - net................
,cc_cco_
16.17 % )...................
Return (rate of return: __
$_'443,916 TOTAL ANNUAL COST OF OPERATION
- 0. Excluding Depreciation
~
O em J
l
o; ATTACR'iENT FOR ITEF. li3.
1.a.
~
ESTIMATED AtiliUAL COST OF OPERATliiG liUCI E R GEliERATIliG UNIT:
Byron 2 FOR THE CALEliDAR YEAR 19_87 (thousandsofdollars)
\\
Operation and maintenance expenses Nuclear po er generation hu: lear fuel expense (plant factor 70 %)...........$
74,409 Other operating expenses.....................
34,719 Maintenance expenses.......................
20,711 Total nuclear power generation.............
129.639 Tra nsmi s s ion exp ens e s t.....'...................
53 A:Sinistrative and genefal expenses Property and liabnity insurance................. __
5.108 11.275 Other A.8G. exp ens es.......................
Total A. &G. expens es.............
16,363
. O -
TOTAL O&M EXPENSES.............'.........
146,275 Depreciation expense.............'............
33,954 Taxes other than incone taxes 5,234 Property taxes............................
7.051 Other................................
Total taxes other than income taxes...........
12.255 34,693 Inccce taxes - Federal.. c.....................
I n ctce t a x e s - o t h e r.........................
5,157 Deferred income taxes - net.......,...'............
47,077
~
Investnent tax credit adjustments - net................
2.0P?
Return (rate of return:
16.17 %)...................
142,461
$ ' 423.9e8 TOTAL Ah.WAL COST OF OPERATION
- o. Excluding Depreciation
.o#
e
~
1.a.
ATTACKMENT FOR ITEM !!0.
~
LSTIMATED ANNUAL COST OF OPERATING NUCI EAR GEtiERATING UNIT:
Byron 2 FOR THE CALEtiDAR YEAR 19_88 (thousands of dollars)
Operation and maintenance expenses Nuclear po er generation
%)...........$
75.637 1.uclear fuel expense (plant factor 70 37,64L Other opera ting expenses.....................
22,575 Maintenance expenses.......................
136.056 Total nuclear power generation.............
58 _
Tra nsrais s ion expens es t.....'...................
Abinistrative and geneva 1 expenses 5,238 Property and liabnity insurance.................
11,815 Other A. &G. exp ens es.......................
17.ns2 Total A.8G. expenses...................~. _,
1 s3. w7 TOTAL OLM EXPENSES.....................
34,364
~
Depreciation expense.........................
Taxes other than incone taxes _
5,391 Property taxes...........................-
6,4%
Oth:r................................
11,e25
~
Total taxes other than income taxes...........
34.990 I n c ce e ta x e s - Fe d e r a l.. <.....................
4,962 I n ctce t a x e s - o th e r.........................
39,872 Deferred income taxes - net... '....,... '............_
2,082 Investnent tax credit adjustments - net................
130.00.3_
Return (rate of return:
16.17 5 ).................. -
411.355_
TOTAL ANNUAL COST OF OPERATION O Excluding Depreciation o
O g
D e
8
r o=
ATTACH",ENT FOR ITEM liO.
1.a.
O ESTIMATED AfiliUAL COST OF OPERATIt!G llUCI EIR GEliEP.ATIliG UlilT: Byron 2 FOR THE CALEriDAR YEAR 198_99 (thousandsofdollars)
Operation and maintenance expenses
~ tiuclear poner generation
%)........... $ 78,464 haclear fuel expense (plant factor vn Other operating expenses.....................
41,250 _
24,606 Maintenance expenses.......................
Total nuclear power generation.............
Ioa.36n Transmission expensest.....'...................
63 Administrative and cenefal expenses s.377 Property and liabnity insurance.................
12.535 Other A.&G. expenses.......................
17,912 Total A.&G. expenses....................
TOTAL OLM EXPENSES.....................
162.315
~
34,811 Depreciation expense.........................
Taxes other than incone taxes 5,552
~ Property taxes............................
5.583 Other............... '.................
Total taxes other than income taxes...........
11,435 35,853 Inccce taxes - Federal.. c.....................
5,329 I n cCCr2 t a x e s - o th e r.........................
Deferred income taxes - net...'....,...'............
32,666 2,062 Investment tax credit adjustments - net................
Return (rate of return:
16.17 %)...................
I2e.ese
$ '403,379 TOTAL ANNUAL COST OF OPERATION l 0 Excluding Depreciation
~
O
(
\\
..._.s
/
~
s/
.O/*r ATTACP?.ENT FOR ITER. lid.
1.a.
~
ESTIMATED AtilmAL COST OF OPERAT!!iG !WCI EAR GEliERATIliG UNIT: Byron 2 FOR THE CALEliDAR YEAR 19,20 (thousandsofdollars)
Operation and maintenance expenses h'uclear power generation _
70 %)........... $ 82,957 h.r. lear fuel expense (plant factor 44,963 Other operating expenses.....................
26,621 Faintenance expenses.......................
1s4.74, Total nuclear power generation.............
~
69 Transmission expensest.....'...................
/
inistrative and geneVal expenses 5,526 Property and liab'11ty insurance.................
13,435 Other A. &G. exp ens es.......................
18.966 Total A.&G. expenses....................
173,774 TOTAL OLM EXPENSES.....................
35,P.co_.
Depreciation expense.........................
Taxes other than incone taxes 5,719 Property taxes.............,...............
9,367 Other................................
11.106 Total taxes other than income taxes...........
37,273 Incocie ta xes - Fe deral.. <.....................
5.540 I n co.e t a x e s - o th e r.........................
25,461 Deferred income taxes - net.......,...'......'... &
2,082 Investment tax credit adjustments - net................
Return (rate of return:, 16.17 %)................... Ice. s e
$ 399,386 _
TOTAL ANtit!AL COST OF OPERATION
- 0. Excluding Depreciation 9
1.
- f. Q~
ATTACKMENT FOR ITEM NO.
1.a.
ESTIPATED ANiiUAL COST OF OPERATING llUCI E R GEliEPATING
'(\\
N UNIT:
Byron 2 FOR THE CALEtiDAR YEAR 1991 (thousandsofdollars)
Operation and maintenance expenses tioclear po,eer ceneration 88,006 tixlear fuel expense (plant factor 70_% )........... $
49.000 Other operating expenses.....................
29.235 Maintenance expenses.......................
16E,250_
Total nuclear power generation.......
75 '
Transmission expensest...................."....
~
Adbinistrative and oenefal expenses 5,686 Property and liab(11ty insurance.................
14,636 Other A. &G. exp ens es.......................
20,12L Total A.&G. expenses....................
186,669 TOTAL DEM EXPENSES.....................
9,iationexpense.........................
35,830_,
~
Dep Taxes other than incone taxes 5,891 Property taxes.............,...............
4.oL7 Oth2r................................
10,e3e Total taxes other than income taxes...........
39.258 Inccce ta xe s - Fe d eral..,-.....................
5,636 I n tcca t a x e s - o th e r.........................
18,256 Deferred income taxes - net...'....,...'......'...e.._
2,082 Investment tax credit adjustments - net................
99,971 16.17 % )...................
Return (rate of return: _
$ ' 398,520 TOTAL ANNUAL COST OF OPERATION o Excluding Depreciation o
O
/
B/B-FSAR QUESTION 010.50 "Your response to QO10.33 concerning the effects of flooding resulting from a failure of the circulating water system transport barrier is incomplete.
You have not provided an adequate response to items (4) & (5) of 0010.33.
Our concern is for the consequences of a major circulating water system leak in the turbine building caused by failures of such non-seismic Cat-egory I components as the main water headers or expansion joints to the condenser coupled with failures of their corresponding butterfly isolation valves.
The potential exists to flood the turbine building basement to the water level elevation of the cooling tower basin (Byron) or the cooling pond (Braidwood) by simple gravity draining from these large reservoirs.
" Describe the designs and locations with the aid of drawings, if necessary, of the watertight barriers provided to prevent floodwater leakage from the turbine building i
to the auxiliary building or any other safety-related enclosure.
Include a discussion of the consideration given to passageways, pipe chases and/or cableways joining the flooded space to space containing safety-related system components.
As an example, discuss the means O
of preventing floodwater from entering the main steam tunnel and eventually reaching the auxiliary building at its termination with the main steam tunnel near the
' safety valve room.
Include in the discussion water exiting the turbine building at or above grade level and entering other safety-related enclosures through watertight barriers removed for maintenance."
RESPONSE
In the event of a circulating water line break which cannot be isolated, the turbine building could theoretically be flooded to grade level at Byron and to 5 feet below grade at Braidwood.
Damage to turbine building equipment will not prevent safe shutdown of the plant because no essential equipment is located in the turbine building.
The auxiliary building is completely watertight below grade at the turbine building auxiliary building interface except for the main steam tunnel.
Watertight closures prevent flooding of the main steam tunnel from affecting the auxiliary feedwater tunnel, the containment, or any other auxiliary building areas.
O Q10.50-1
O)
(,
B/B-FSAR
()
The only safety-related items which will be affected by turbine building flooding are the main steam isolation valves (MSIV's).
With a loss of power, the MSIV's will fail as is.
The steamlines are automatically isolated on high containment pressure or low steamline pressure signals.
If the event which damages the circulating water piping also causes a significant break in a main steamline, the resulting decrease in pressure will cause MSIV closure prior to MSIV inoperability.
In the event that the turbine system remains intact following a circulating water piping failure, the turbine will be tripped and the turbine stop valves will isolate the s'.eam system.
Failure of the MSIV's will not have an adverse affect.
The only lines which will not be automatically isolated on a turbine trip are the takeoffs to the gland sealing steam and steam jet air ejectors.
The 4 inch gland steamline utilizes a motor-operated isolation valve which will be closed by the operator after a turbine trip.
The line to the steam jet and ejectors contains a 2-inch manual isolation valve.
Failure to close this valve will result in a blowdown from the main steamline of approximately 1000 lb/hr (60 gpm).
This small amount will not affect the safe shutdown of the unit.
In addition, there are no main steam or turbine valves located below grade other than the MSIV's.
(
One fully severed circulating water pipe would provide suf-ficient flow into the turbine building to flood the MSIV's in about 10 minutes.
This is not realistic because a guillo-l tine break of this pipe would require an 8 foot lateral motion of the pipe.
A large break in the circulating water system would quickly be evident to operating personnel and action would be taken to secure the main steam system.
However, as discussed above, the only concern in this case is the possibility of gross failure of the main steam piping in conjunction with the circulating water pipe failure and this event results in MSIV closure prior to flooding.
If the main steam system is intact, the MSIV's may fail open l
without impact on plant safety.
l l
O Q10.50-2
\\
B/B-FSAR QUESTION 022.25 "FSAR Section 6.5.2.2 states ' Containment spray injection and caustic education...will continue until...the low-low level alarm of the RWST is annunciated.
Containment spray injection and caustic addition may then be terminated, and the operating personnel may transfer the containment spray pumps from the. injection to the recirculation mode by first closing the motor-operated valves in the suction line from the RWST, the water and caustic lines to the eductor, and then opening the motor-operated valves in the suction lines from the containment sumps.'
State clearly whether transferring the containment spray pumps from the injection to the recirculation mode involves stopping and restarting the containment spray pumps as implied in the above statement because the valves in the suction line from the RWST are closed before the valves in the suction lines from the containment sump; are opened."
RESPONSE
The containment spray pumps will be run for at least 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> following a LOCA.
During this time, switchover of pump
'l suction from the injection to the recirculation mode of operation will be manually initiated and completed.
The containment spray pumps do not have to be stopped when transferring from the injection mode to the recirculation mode of operation.
The response to Question 450.2 from the Accident Analysis Branch provides a more detailed discussion on this subject.
A summary of the sequence of events leading up to and during switchover follows.
The RWST level is initially one volume inaccuracy below the low alarm setpoint.
RWST outflow during injection 18,200 gpm per CAW-3942 (CBW-2526).
ECCS switchover begins at one volume inaccuracy below the low-low alarm setpoint.
The volume consumed prior to switchover is 257,454 gallons and requires 14.15 minutes.
ECCS switchover is given in Table 0212.65-2 in response to Question 212.65.
It requires 235 seconds (3.92 min.) and consumes 73,618 gallons assuming two trains and worst single failure.
Following completion of ECCS switchover, the outflow from the RWST is 14,400 gpm and continues until 20.9 minutes have elapsed, consuming an additional 40,752 gallons.
Q22.25-1
A k,)
B/B-FSAR
()
Spray switchover begins at 20.9 minutes, and is completed when 21.6 minutes have elapsed, consuming an additional 10,080 gallons.
Total cumulative volume used is 381,904 gallons.
At this time 24,948 gallons are still available one volume inaccuracy above the nominal empty alarm setpoint.
See Table Q22.25-1.
When containment spray is initiated 25 seconds after the start of injection, the operator verifies that flow is present from the spray additive tank for both trains.
Assuming the single failure is failure of the then spray additive e3uctor valve opens.
The operator turns off the pump in the train with the failed valve.
In this mode of operation, the cumulative volume used at the time ECCS switchover is complete is 262,496 gallons.
While the ECCS pumps are operating from the recirculation sump, the one operating spray pump continues to take suction from the RWST until the RWST level is one volume inaccuracy above the nominal empty alarm setpoint.
This occurs at 31.7 minutes.
At thin time the spray pump is switched to the recirculation mode.
Spray switchover is complete at 32.4 minutes.
In order to obtain the long term required sump pH, a minimum of 2100 gallons of 30% NaOH is required from the spray additive tank.
After 32.4 minutes, another 357 gallons is required O
to be added.
This can be accomplished by continuing caustic addition for another 6.5 minutes while the spray pump is taking suction from the sump.
See Table Q22.25-2.
022.25-2
(
B/B-FSAR O
TABLE Q22.25-1 SINGLE FAILURE - WORST CASE ECCS ELAPSED PHASE CUMULATIVE TIME OF VOLUME USED (MINUTES)
ACCIDENT (GAL) 0 Begin injecEion 0
14.15 Begin ECCS 257,454 switchover 18.07 ECCS switchover 331,072 complete 20.9 Begin spray 371,824 switchover 21.6 Spray switchover 381,904 complete l
i l
O Q22.25-3
h B/B-FSAR O
TABLE Q22.25-2 SINGLE FAILURE - WORST CASE CONTAINMENT SPRAY SYSTEM ELAPSED PHASE CUMULATIVE TIME
'OF VOLUME USED (MINUTES)
ACCIDENT (GAL) 0 Begin injection 0
14.15 Begin ECCS 203,755 switchover 18.07 ECCS switchover 262,496 complete 31.7 Begin Spray 406,852 switchover 32.4 Spray switchover 409,151 complete O
38.9 Spray additive addition complete l
O Q22.25-4
k
(-)
B/B-FSAR
()
QUESTION 040.120
" Expand your description of the diesel engine starting system.
The FSAR test should provide a detailed system description of what is shown on Figure 9.5.3.
The FSAR tex'c should also describe:
- 1) components and their
- function,
- 2) instrumentation, controls, sensors and alarms, and
- 3) a diesel engine starting sequence.
In describing the diesel engine starting sequence include the number of air start valves used and whether one or both air start systems are used."
RESPONSE
General The engine is started using compressed air (250 psi), furnished by two separate motor driven air compressors mounted on the starting air skid.
Each compressor pumps air through a check valve past a relief valve through a refrigerant type dryer into an air tank.
This is a dual system with either half capable of starting the engine.
O-'
' Compressed air from the starting air tanks is applied tothe starting air contr controlled by starting air solenoid valves.
When the starting air control valves open, starting air is supplied to both banks of air start valves and air distributors.
One start valve is located in each cylinder head and all are controlled by the air distributors.
Normally both starting air control valves open simultaneously and air is taken from both tanks.
If a malfunction occurs and one of the control valves fail to open, the crossover piping will admit air to the other bank of cylinders.
As the air tanks lose pressure, the compressors start to replenish the air supply.
If both compressors are inoperative, the air tanks have sufficient capacity to provide four starts with the existing pressure in the tanks.
Each individual air tank has sufficient capacity to provide for four starts.
The piping between the air start valve and the air control valve is continuously purged with combustion air from the turbocharger discharge.
This compressed air, approximately 300* F in temperature, prevents the possibility of an explosion due to a leaky air start valve and prevents any moisture Q40.120-1
D/B-FSAR b
Q condensation buildup in the air start piping.
In the unlikely
{)')
event that some condensation occurs when the turbocharger purging air cools to ambient temperature, the line filter s
in the air start piping, located between the air start valve and air distributor, will collect the moisture.
In addition, the filter contains a sight glass to show any water collected.
The arrangement of the air start piping prevents any possible condensation from accumulating on the air start valves.
Cooper Besrumer states that they have not experienced any problems to date with corrosion of the starting air system as designed.
Starting Air Controls Air applied to the starting air control valve is blocked but flows out an alternate port through a check valve to the manual control air valves.
If all four shut-off valves are open, control air flows through the shuttle valve to the engine controls and shuts down and through filters to the interlock valves.
If the turning gear is disengaged, these interlock valves are open and air flows to the solenoid valves.
If these solenoid valves are activated, air flows through them and a shuttle valve, thus admitting air to the distributors and air stdrt valves in each cylinder head.
/~'
.When the starting signal is turned off, air vents from the distributors and cylinder heads through the orificed check valves and out the vents in starting air control valves.
Air Compressors A panel on the air tank contains a pressure gauge, pressure switches to start and stop the compressor automatically, test valves and connections and shutoff valves.
The compres-sors can also be started by manually setting the switch on the local control panel to the " HAND" position.
Each compressor isdrjvenbya15hpmotoranddelivers 32.2 cfm to the 96 ft air tank.
Due to the interconnecting piping, both tanks should be depleted at the same rate.
Therefore, both compressorn will start to replenish the air supply at approximately the same time.
The pressure switches on each air tank panel start the compressor at 240 psi falling and stop it at 250 psi.
Pressure relief valves are set at 265 psi.
Q40.120-2
BYRON-FSAR f%(,
RESPONSE
A.
TABLE 3.2-1 ITEMS As discussed in Section 3.2, Table 3.2-1 lists princi-pal structures, systems, and components and identifies the safety category and quality group of these items.
Although it is not feasible to include each component in this table, an attempt has been made to illustrate the approach used in assigning the safety category and quality group.
As noted in Section 3.2.1.1, the safety category of each' piping run, valve, etc. and the divisions between Safety Category I and II can be deter-mined from the P&ID's.
(The response to Question 212.7 lists all P&ID's in the PSAR.
In addition, one full size set of P&ID's was transmitted to the NRC in March, 1979, along with the response to Question 212.7.).
Each of the items identified in part of this question has been investigated.
The results are listed below by item number.
1.
The safety category for the Auxiliary Building, Fuel Handling Building, and other structures is listed in Table 3.2-1 under Section I-l and I-2.
This safety category also applies to internal structures within the identified buildings.
2.
See Item 1 response.
,O
(_)
3.
All containment penetrations and isolation valves are Safety Category I regardless of the safety I classification of the system.
Because of the large number of penetrations involved, these are not identified individually in Table 3.2-1.
The containment penetrations and isolation valves are listed in Table 6.2-58 and may be found on the system P&ID's.
4.
The fuel assemblies are designated by Westinghouse as ANS Safety Class 2 components.
They are designed and fabricated under the full provisions of a 10CFR50 Appendix B quality assurance program.
They will also be subject to the pertinent requirements of the operational quality assurance program.
5.
The control rod assemblies are designated by Westinghouse as ANS Safety Class 2 components.
They are designed and fabricated under the full provisions of a 10CFR50 Appendix B quality assurance program.
They will also be subject to the pertinent requirements of the operational quality assurance program.
6.
Reactor internals are included already in Table 3.2-1 as part of Item II.64.a.
0421.22-6
ornua-ranx O
7.
See item 6.
- '\\
8.
This is included in Item II.70.a.
[s
/
9.
This is included in Item II.70.a of Table 3.2-1.
I 10.
This is already included in Table 3.2-1 as Item II.64.
11.
These components are Category I.
As previously noted, Table 3.2-1 illustrates the Safety Category and Quality Group breakdown for. principle structures, systems and components only.
12.
This is included in Item II.64.d.
13.
These valves are Category I.
As previously noted, 3
Table 3.2-1 illustrates the Safety Category and Quality Group breakdown for principle structures, systems and components only.
14.
These components are Category I.
As previously noted, i
Table 3.2-1 illustrates the Safety Category and Quality Group breakdown for principle structures, systems and components only.
15.
These valves are Category I.
As noted in Section 3.2.1.1, the safety category of piping and valves may be found on the system P&ID 's.
As previously noted, Table 3.2-1 illustrates the Safety Category and Quality Group
(
breakdown for principle structures, systems and j
components.
16.
These valves are Category I.
As noted in Section 3.2.1.1, the safety category of piping and valves may be found on the system P&ID's.
As previously noted, Table 3.2-1 illustrated the Safety Category and Quality Group breakdown for principle structures, systems and components only.
17.
This piping and valves are Category I.
This is noted on the system P&ID's.
Table 3.2-1 is intended to list principle structures, systems and components only.
18.
As noted in Table 3. 2-1, Item II-ll, the Condensate Systen is Safety Category II.
However, portinent requirements of the operational QA program will be applied to this system.
As shown in Item II.3, the Auxiliary Feed Water System is Category I.
19.
No air operated valves perform a safety function on the Byron /Braidwood stations.
tU 0421.22-7
]
BYRON-FSAR 20.
See Item 1.
21.
See Item 1.
22.
See Item 1.
l 23.
This component is Category I.
See Item II.31 of Table 3.2-1.
Table 3.2-1 is intended to list principle structures, systems, and components only.
24.
These components are Category I, and are included in Table 3.2-1 order Item II.65.
25.
See item 23.
i l
O, I
O t
0421.22-7a i
9
-,.yy.
,,,,,_m.__.__y
. m
26.
The cask io handled by the Fuel Handling Building crane which is listed in Table 3.2-1 (Item II-31u).
(~N 27.
See item 23.
28.
See item 23.
29.
As noted in Section 3.2.1.1, the safety category of piping and valves may be found on the system P&ID's.
As previously noted, Table 3.2-1 illustrates the Safety Category and Quality Group breakdown for principal structures, systems and components only.
30.
See Item 1.
31.
The safety category for supports is the same as the pipe or equipment being supported.
Items I-2a and I-2b in Table 3.2-1 are being revised to clarify this.
32.
See Item 29.
33.
a.
H2 monitoring system will be added to Table 3.2.1.
Tnis is a Category I system.
b.
H2 analyzer will be added to Table 3.2-1.
This is a Category I system.
c.
See Item 31.
O
' 34. -
the RCFC Essential Service Water Coils are a.
As shown in Table 3.2-1, Items II-98n and II-98o, Category I.
b.
As discussed in response to Item 31, the dampers and supports necessary for operation of Category I systems are designed as Category I.
35.
a.
The hydrogen recombiners listed in Table 3.2-1, Item II-53a.
b.
Not applicable.
c.
See Item 29.
36.
See Item 31.
37.
This equipment is already covered by Item II.19 of Table 3.2-1.
38.
This equipment is covered under Item II.20 of Table 3.2-1.
39.
Item II-44a includes all equipment necessary for Category I Instruments and Control to perform their safety func-tion.
0421.22-8
BYRON-FSAR 40.
Although not all components in the Control Room HVAC system were designed as Category I components, the pertinent provisions of the operational phase QA O.
program will be applied to this entire system.
Control room HVAC equipment is treated as follows:
h.
Humidifier will be added to Table 3.2-1.
i.
The Condenser is included in Table 3.2-1, Item II-88.d.
j.
Charcoal Filter housing will be added to Table 3.2-1.
k.
Ductwork and dampers are not included in this table.
The safety category may be found from the P&ID's or equipment lists as noted in Section 3.2.1.1.
1.
The control room HVAC does not have safety isolation valves.
The utility exhaust fan will be added to m.
Table 3.2-1.
Electrical modules witIh safety functions are n.
included in Table 3.2-1, Item II-88f.
Ot Table 3.2-1, Item II-88f.
Cables with safety functions are included in o.
I 41.
See Item 29.
42.
The fixed equipment is covered under Item II.6 of Table 3.2-1.
Although not all components of this system were designed as Category I components, per-tinent requirements of the operational phase QA l
program will be applied to this system.
Portable equipment is purchased under site QA and thus is not included in Table 3.2-1.
43.
The fixed equipment is covered under Item II.61 of Table 3.2-1.
Although not all components of this system were designed as Category I components, pertinent requirements of the operational phase QA program will be applied to this system.
Portable equipment is purchased under site QA and thus is not included in Table 3.2-1.
44.
This equipment is covered under Item II.61 and 62 of Table 3.2-1.
Although not all components of this system were designed as Category I components, pertinent requirements of the opeational phase QA program will be applied to this system.
A.
0421.22-9
~
45.
This item does not constitute principle structurou, pI systems, or components of the plant, and thus is not
(*^s' included in Table 3.2-1.
This activity will be conducted under the pertinent requirements of the operational QA program.
"h) 46.
See Item 45.
V 47.
See Item 45.
48.
See Item 45.
49.
See Item 45.
50.
See Item 1.
51.
See Item 31.
B.
NUREG-0737 ITEMS
'NUREG-0737 Items are addressed in Appendix E.
As discussed previously, Table 3.2-1 gives general information on the safety classification of equipment corrections required as a result of NUREG-0737 items have been made to Table 3.2-1 but not all NUREG-0737 items correspond to Table 3.2-1 items.
The items listed have been investigated and are discussed here.
1.
The plant safety-parameter display console is being installed at Byron /Braidwood stations.
(See Section E17)
This is included in Table 3.2-1, Item II.60.a.
()
2.
The Reactor Coolant System Vents are discussed in Section E.19.
This is included in Table 3.2-1, Item
- II.64.a.
3.
NUREG-0737, Item II.B.2, Plant Shielding, is a design review of the plant shielding and postaccident.
radiation levels and therefore, does not directly involve plant structures or equipment.
As discussed i
in response to Part A.1 of this question, safety category of shielding is equivalent to that of the building in which it is located.
l 4.
The post accident sampling capabilities are discussed in Section E.21.
This system is included in Table 3.2-1, Item II.62, and is a Category I system.
5.
The indication of relief and safety valve position is explained and the safety category requirements discussed in detail in Section E.24.
The instrumentation is the same safety' category as the valves it is provided
- for, i.e.,
Category I.
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6.
The auxiliary feedwater system is discussed in Section E.25 and included in Table 3.2-1, Item II.3.
Q421.22-10 i
l
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