[Federal Register Volume 69, Number 39 (Friday, February 27, 2004)]
[Rules and Regulations]
[Pages 9388-9398]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 04-4341]


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NUCLEAR REGULATORY COMMISSION

[Docket Nos. (as shown in the Attachment), License Nos. (as shown in 
the Attachment), EA-03-009]


In the Matter of All Pressurized Water Reactor Licensees; First 
Revised Order Modifying Licenses

I

    The Licensees identified in the Attachment to this Order hold 
licenses issued by the Nuclear Regulatory Commission (NRC or 
Commission) authorizing operation of pressurized water reactor (PWR) 
nuclear power plants in accordance with the Atomic Energy Act of 1954 
and title 10 of the Code of Federal Regulations (10 CFR) part 50.

II

    The reactor pressure vessel (RPV) heads of PWRs have penetrations 
for control rod drive mechanisms and instrumentation systems. Nickel-
based alloys (e.g., Alloy 600) are used in the penetration nozzles and 
related welds. Primary coolant water and the operating conditions of 
PWR plants can cause cracking of these nickel-based alloys through a 
process called primary water stress corrosion cracking (PWSCC). The 
susceptibility of RPV head penetrations to PWSCC appears to be strongly 
linked to the operating time and temperature of the RPV head. Problems 
related to PWSCC have, therefore, increased as plants have operated for 
longer periods of time. Inspections of the RPV head nozzles at the 
Oconee Nuclear Station, Units 2 and 3 (Oconee), in early 2001 
identified circumferential cracking of the nozzles above the J-groove 
weld, which joins the nozzle to the RPV head. Circumferential cracking 
above the J-groove weld is a safety concern because of the possibility 
of a nozzle ejection if the circumferential cracking is not detected 
and repaired.
    Section XI of the American Society of Mechanical Engineers Boiler 
and Pressure Vessel Code (ASME Code), which is incorporated into NRC 
regulations by 10 CFR 50.55a, ``Codes and standards,'' currently 
specifies that inspections of the RPV head need only include a visual 
check for leakage on the insulated surface or surrounding area. These 
inspections may not detect small

[[Page 9389]]

amounts of leakage from an RPV head penetration with cracks extending 
through the nozzle or the J-groove weld. Such leakage can create an 
environment that leads to circumferential cracks in RPV head 
penetration nozzles or corrosion of the RPV head. In response to the 
inspection findings at Oconee and because existing requirements in the 
ASME Code and NRC regulations do not adequately address inspections of 
RPV head penetrations for degradation due to PWSCC, the NRC issued 
Bulletin 2001-01, ``Circumferential Cracking of Reactor Pressure Vessel 
Head Penetration Nozzles,'' dated August 3, 2001. In response to the 
bulletin, PWR licensees provided their plans for inspecting RPV head 
penetrations and the outside surface of the heads to determine whether 
any nozzles were leaking.
    In early March 2002, while conducting inspections of RPV head 
penetrations prompted by Bulletin 2001-01, the licensee for the Davis-
Besse Nuclear Power Station (Davis-Besse) identified a cavity in the 
RPV head near the top of the dome. The cavity was next to a leaking 
nozzle with a through-wall axial crack and was in an area of the RPV 
head that the licensee had left covered with boric acid deposits for 
several years. On March 18, 2002, the NRC issued Bulletin 2002-01, 
``Reactor Pressure Vessel Head Degradation and Reactor Coolant Pressure 
Boundary Integrity,'' which requested PWR licensees to provide 
information on their RPV head inspection and maintenance programs, the 
material condition of their reactor vessel heads, and their boric acid 
inspection programs. In their responses, the licensees provided 
information about their boric acid inspection programs and their 
inspections and assessments to ensure that their respective plant did 
not have reactor vessel head degradation like that identified at Davis-
Besse.
    The experience at Davis-Besse and the discovery of leaks and nozzle 
cracking at other plants reinforced the need for more effective 
inspections of RPV head penetration nozzles. The absence of an 
effective inspection regime could, over time, result in unacceptable 
circumferential cracks in RPV head penetration nozzles or in the 
degradation of the RPV head by corrosion. These degradation mechanisms 
increase the probability of a more significant loss of reactor coolant 
pressure boundary through ejection of a nozzle or other rupture of the 
RPV head. The NRC issued Bulletin 2002-02, ``Reactor Pressure Vessel 
Head and Vessel Head Penetration Nozzle Inspection Programs,'' dated 
August 9, 2002, requesting that licensees provide information about 
their inspection programs and any plans to supplement existing visual 
inspections with additional measures (e.g., volumetric and surface 
examinations). Licensees have responded to Bulletin 2002-02 with 
descriptions of their inspection plans for at least the first refueling 
outage following the issuance of Bulletin 2002-02 or with a schedule to 
submit such descriptions before the next refueling outage. Many of the 
licensees' responses to Bulletin 2002-02 did not describe long-term 
inspection plans. Instead the licensees stated that they would follow 
guidance being developed by the industry-sponsored Materials 
Reliability Program.
    Inspections performed at several PWR plants in late 2002 found 
leakage and cracks in nozzles or J-groove welds that have required 
repairs or prompted the replacement of the RPV head. In addition, as 
discussed in NRC Information Notice 2003-02, ``Recent Experience with 
Reactor Coolant System Leakage and Boric Acid Corrosion,'' issued 
January 16, 2003, leakage has recently occurred at some plants from 
connections above the RPV head and has required additional assessments 
and inspections to ensure that the leakage has not caused significant 
degradation of RPV heads.
    The NRC issued an Order Modifying Licenses (Effective Immediately) 
(EA-03-009), dated February 11, 2003 (Order), to establish required 
inspections of RPV heads and associated penetration nozzles at PWRs. 
These requirements were necessary to provide reasonable assurance that 
plant operations did not pose an undue risk to the public health and 
safety. The requirements of that Order were expected to remain in 
effect pending long-term resolution of RPV head penetration inspection 
requirements, which is expected to involve changes to the NRC 
regulations, specifically 10 CFR 50.55a. Research being conducted by 
the NRC and industry is increasing our understanding of material 
performance, improving inspection capabilities, and supporting 
assessments of the risks to public health and safety associated with 
potential degradation of the RPV head and associated penetration 
nozzles. These research activities are important to the long-term 
development of revisions to the NRC regulations.

III

    Revising the NRC regulations will take several years. The 
licensees' actions to date in response to the NRC bulletins and the 
February 11, 2003, Order have provided reasonable assurance of adequate 
protection of public health and safety. That Order required inspections 
of RPV heads and associated penetration nozzles at PWRs which were 
necessary to provide reasonable assurance that plant operations do not 
pose an undue risk to the public health and safety.
    Since the issuance of that Order, the NRC staff has reviewed and 
granted many requests for relaxation thereof. The arguments in the 
relaxation requests provide reasonable assurance of the continued 
structural integrity of the RPV head, and the associated nozzle 
penetrations and J-groove welds. As a result, it is appropriate to 
revise that Order with respect to bare metal visual inspections, 
penetration nozzle inspection coverage, flexibility in combining 
nondestructive examination (NDE) methods, flaw evaluation, and 
requirements for plants which have replaced their reactor pressure 
vessel head.
    It is appropriate and necessary to the protection of public health 
and safety to establish a clear regulatory framework, pending the 
incorporation of revised inspection requirements into 10 CFR 50.55a. To 
provide reasonable assurance of adequate protection of public health 
and safety for the interim period, all PWR Licenses identified in the 
Attachment to this Order shall be modified to include the inspection 
requirements for RPV heads and associated penetration nozzles 
identified in section IV of this Order. The NRC requirements imposed by 
this Order are based on the body of evidence available through December 
2003. Continuing research and operating experience may support future 
changes to the requirements imposed through this Order.

IV

    Accordingly, pursuant to sections 103, 104b, 161b, 161i, 161o, 182, 
and 186 of the Atomic Energy Act of 1954, as amended, and the 
Commission's regulations in 10 CFR 2.202 and 10 CFR part 50, it is 
hereby ordered that all licenses identified in the Attachment to this 
Order are modified as follows:
    A. To determine the required inspection(s) for each refueling 
outage at their facility, all Licensees shall calculate the 
susceptibility category of each RPV head to PWSCC-related degradation, 
as represented by a value of effective degradation years (EDY) for the 
end of each operating cycle, using the following equation:

[[Page 9390]]

[GRAPHIC] [TIFF OMITTED] TN27FE04.000

Where:

EDY = total effective degradation years, normalized to a reference 
temperature of 600 F
[Delta]EFPYj = operating time in years at Thead,j
Qi = activation energy for crack initiation (50 kcal/mole)
R = universal gas constant (1.103x10-\3\ kcal/mole R)
Thead,j = 100 percent power head temperature during time period j 
(R = F + 459.67)
Tref = reference temperature (600 F = 1059.67 R)
n = number of different head temperatures during plant history

    This calculation shall be performed with best estimate values for 
each parameter at the end of each operating cycle for the RPV head that 
will be in service during the subsequent operating cycle. The 
calculated value of EDY shall determine the susceptibility category and 
the appropriate inspection for the RPV head during each refueling 
outage.
    B. All Licensees shall use the following criteria to assign the RPV 
head at their facility to the appropriate PWSCC susceptibility 
category:

High:
    (1) Plants with a calculated value of EDY greater than 12, or
    (2) Plants with an RPV head that has experienced cracking in a 
penetration nozzle or J-groove weld due to PWSCC.
Moderate: Plants with a calculated value of EDY less than or equal to 
12 and greater than or equal to 8 and no previous inspection findings 
requiring classification as High.
Low: Plants with a calculated value of EDY less than 8 and no previous 
inspection findings requiring classification as High.
Replaced: Plants with a replaced RPV head and with a calculated value 
of EDY less than 8 AND no previous inspection findings requiring 
classification as High.
    C. All Licensees shall perform inspections of the RPV head \1\ 
using the following frequencies \2\ and techniques:
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    \1\ This Order imposes additional inspection requirements. 
Licensees are required to address any findings from these 
inspections (i.e., perform analyses and repairs) in accordance with 
existing requirements in the ASME Code and 10 CFR 50.55a. The NRC 
has issued guidance to address flaw evaluations for RPV head 
penetration nozzles (see letter dated April 11, 2003, from R. 
Barrett, NRC, to A. Marion, Nuclear Energy Institute, ADAMS 
Accession No. ML030980322) and will, as necessary, issue revised 
guidance pending the updating of the NRC regulations.
    \2\ The requirements of this Order are generally consistent with 
inspection plans that the NRC staff accepted in letters to some 
Licensees regarding their responses to Bulletin 2002-02. If the NRC 
staff has already accepted a specific variation from the 
requirements of this Order (e.g., inspections to less than 2 inches 
above the J-groove weld), the Licensee may continue with the 
previously accepted inspection plan for the first refueling outage 
after February 11, 2003, provided that in its response to this Order 
the Licensee identifies all discrepancies between the requirements 
of this Order and the previously accepted inspection plan. Licensees 
proposing to deviate from the requirements of this Order for 
subsequent refueling outages shall seek relaxation of this Order 
pursuant to the procedure specified at the end of this section.
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    (1) For those plants in the High category, RPV head and head 
penetration nozzle inspections shall be performed using the techniques 
of paragraph IV.C.(5)(a) and paragraph IV.C.(5)(b) every refueling 
outage.\3\
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    \3\ For repaired RPV head penetration nozzles that establish a 
new pressure boundary, the ultrasonic testing inspection shall 
include the weld and at least 1-inch above the weld in the nozzle 
base material. For RPV head penetration nozzles or J-groove welds 
repaired using a weld overlay, the overlay shall be examined by 
either ultrasonic, eddy current, or dye penetrant testing in 
addition to the examinations required by paragraph IV.C.(5)(a) and 
paragraph IV.(C).(5)(b).
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    (2) For those plants in the Moderate category, RPV head and head 
penetration inspections shall be performed such that at least the 
requirements of paragraph IV.C.(5)(a) or paragraph IV.C.(5)(b) are 
performed each refueling outage. In addition the requirements of 
paragraph IV.C.(5)(a) and paragraph IV.C.(5)(b) shall each be performed 
at least once over the course of every 2 refueling outages.
    (3) For those plants in the Low category, RPV head and head 
penetration nozzle inspections shall be performed as follows. An 
inspection meeting the requirements of paragraph IV.C.(5)(a) must be 
completed at least every third refueling outage or every 5 years, 
whichever occurs first. If an inspection meeting the requirements of 
paragraph IV.C.(5)(a) was not performed during the last refueling 
outage prior to February 11, 2003, the Licensee must complete an 
inspection meeting the requirements of paragraph IV.C.(5)(a) within the 
first 2 refueling outages after February 11, 2003. The requirements of 
paragraph IV.C.(5)(b) must be completed at least once prior to February 
11, 2008, and thereafter, at least every 4 refueling outages or every 7 
years, whichever occurs first.
    (4) For those plants in the Replaced category, no RPV head and head 
penetration nozzle inspections shall be required during the outage for 
which the RPV head was replaced. Thereafter, until the replacement RPV 
head in accordance with paragraph IV.A reaches 8 EDY, RPV head and head 
penetration nozzle inspections shall be performed as follows. An 
inspection meeting the requirements of paragraph IV.C.(5)(a) must be 
completed at least every third refueling outage or every 5 years, 
whichever occurs first. The requirements of paragraph IV.C.(5)(b) must 
be completed at least every 4 refueling outages or every 7 years, 
whichever occurs first.
    (5) Inspections of the RPV head shall be performed as directed in 
paragraphs IV.C.(1), IV.C.(2), IV.C.(3) and IV.C.(4) using the 
following techniques:
    (a) Bare metal visual examination of 100 percent of the RPV head 
surface (including 360 around each RPV head penetration nozzle). 
For RPV heads with the surface obscured by support structure 
interferences which are located at RPV head elevations downslope from 
the outermost RPV head penetration, a bare metal visual inspection of 
no less than 95 percent of the RPV head surface may be performed 
provided that the examination shall include those areas of the RPV head 
upslope and downslope from the support structure interference to 
identify any evidence of boron or corrosive product. Should any 
evidence of boron or corrosive product be identified, the licensee 
shall examine the RPV head surface under the support structure to 
ensure that the RPV head is not degraded.
    (b) For each penetration, perform a nonvisual NDE in accordance 
with either (i), (ii) or (iii):
    (i) Ultrasonic testing of the RPV head penetration nozzle volume 
(i.e., nozzle base material) from 2 inches above the highest point of 
the root of the J-groove weld (on a horizontal plane perpendicular to 
the nozzle axis) to 2

[[Page 9391]]

inches below the lowest point at the toe of the J-groove weld on a 
horizontal plane perpendicular to the nozzle axis (or the bottom of the 
nozzle if less than 2 inches (see Figure IV-1)); or from 2 inches above 
the highest point of the root of the J-groove weld (on a horizontal 
plane perpendicular to the nozzle axis) to 1.0-inch below the lowest 
point at the toe of the J-groove weld (on a horizontal plane 
perpendicular to the nozzle axis) and including all RPV head 
penetration nozzle surfaces below the J-groove weld that have an 
operating stress level (including all residual and normal operation 
stresses) of 20 ksi tension and greater (see Figure IV-2). In addition, 
an assessment shall be made to determine if leakage has occurred into 
the annulus between the RPV head penetration nozzle and the RPV head 
low-alloy steel.
    (ii) Eddy current testing or dye penetrant testing of the entire 
wetted surface of the J-groove weld and the wetted surface of the RPV 
head penetration nozzle base material from at least 2 inches above the 
highest point of the root of the J-groove weld (on a horizontal plane 
perpendicular to the nozzle axis) to 2 inches below the lowest point at 
the toe of the J-groove weld on a horizontal plane perpendicular to the 
nozzle axis (or the bottom of the nozzle if less than 2 inches (see 
Figure IV-3)); or from 2 inches above the highest point of the root of 
the J-groove weld (on a horizontal plane perpendicular to the nozzle 
axis) to 1.0-inch below the lowest point at the toe of the J-groove 
weld (on a horizontal plane perpendicular to the nozzle axis) and 
including all RPV head penetration nozzle surfaces below the J-groove 
weld that have an operating stress level (including all residual and 
normal operation stresses) of 20 ksi tension and greater (see Figure 
IV-4).
    (iii) A combination of (i) and (ii) to cover equivalent volumes, 
surfaces and leak paths of the RPV head penetration nozzle base 
material and J-groove weld as described in (i) and (ii). Substitution 
of a portion of a volumetric exam on a nozzle with a surface 
examination may be performed with the following requirements:
    1. On nozzle material below the J-groove weld, both the outside 
diameter and inside diameter surfaces of the nozzle must be examined.
    2. On nozzle material above the J-groove weld, surface examination 
of the inside diameter surface of the nozzle is permitted provided a 
surface examination of the J-groove weld is also performed.
BILLING CODE 7590-01-P

[[Page 9392]]

[GRAPHIC] [TIFF OMITTED] TN27FE04.001


[[Page 9393]]


[GRAPHIC] [TIFF OMITTED] TN27FE04.002


[[Page 9394]]


[GRAPHIC] [TIFF OMITTED] TN27FE04.003


[[Page 9395]]


[GRAPHIC] [TIFF OMITTED] TN27FE04.004

BILLING CODE 7590-01-C
    D. During each refueling outage, visual inspections shall be 
performed to identify potential boric acid leaks from pressure-
retaining components above the RPV head. For any plant with boron 
deposits on the surface of the RPV head or related insulation, 
discovered either during the inspections required by this Order or 
otherwise and regardless of the source of the deposit, before returning 
the plant to operation the Licensee shall perform inspections of the 
affected RPV head surface and penetrations appropriate to the 
conditions found to verify the integrity of the affected area and 
penetrations.
    E. For each inspection required in Paragraph C, the Licensee shall 
submit a report detailing the inspection results within sixty (60) days 
after returning the plant to operation. For each inspection required in 
Paragraph D, the Licensee shall submit a report detailing the 
inspection results within sixty (60) days after returning the plant to 
operation if a leak or boron deposit was found during the inspection.
    F. In the response required by section V of this Order, all 
Licensees shall notify the Commission if (1) they are unable to comply 
with any of the requirements of section IV or (2) compliance with any 
of the requirements of section IV is unnecessary. Licensees proposing 
to deviate from the requirements of this Order shall seek relaxation of 
this Order pursuant to the procedure specified below.
    Project Directors or higher management positions in the Division of 
Licensing Project Management of the Office of Nuclear Reactor 
Regulation may, in writing, relax or rescind any of the above 
conditions upon demonstration by the Licensee of good cause. A request 
for relaxation regarding inspection of specific nozzles shall also 
address the following criteria:
    (1) The proposed alternative(s) for inspection of specific nozzles 
will provide an acceptable level of quality and safety, or
    (2) Compliance with this Order for specific nozzles would result in 
hardship or unusual difficulty without a compensating increase in the 
level of quality and safety.
    Requests for relaxation associated with specific penetration 
nozzles will be evaluated by the NRC staff using its procedure for 
evaluating proposed alternatives to the ASME Code in accordance with 10 
CFR 50.55a(a)(3).

V

    In accordance with 10 CFR 2.202, the Licensee must, and any other 
person adversely affected by this Order may, submit an answer to this 
Order, and may request a hearing on this Order, within 20 days of the 
date of this Order. Where good cause is shown, consideration will be 
given to extending the time to request a hearing. A request for 
extension of time in which to submit an answer or request a hearing 
must be

[[Page 9396]]

made in writing to the Director, Office of Nuclear Reactor Regulation, 
Nuclear Regulatory Commission, Washington, DC 20555, and must include a 
statement of good cause for the extension. The answer may consent to 
this Order. Unless the answer consents to this Order, the answer shall, 
in writing and under oath or affirmation, specifically set forth the 
matters of fact and law on which the Licensee or other person adversely 
affected relies and the reasons as to why the Order should not have 
been issued. Any answer or request for a hearing shall be submitted to 
the Secretary, Office of the Secretary of the Commission, Nuclear 
Regulatory Commission, Attn: Rulemakings and Adjudications Staff, 
Washington, DC 20555. Copies shall also be sent to the Director, Office 
of Nuclear Reactor Regulation, U. S. Nuclear Regulatory Commission, 
Washington, DC 20555; to the Assistant General Counsel for Materials 
Litigation and Enforcement at the same address; to the Document Control 
Desk at the same address; to the Regional Administrator for NRC Region 
I, II, III, or IV, as appropriate for the specific plant; and to the 
Licensee if the answer or hearing request is by a person other than the 
Licensee. Because of possible disruptions in delivery of mail to United 
States government offices, it is requested that answers and requests 
for hearing be transmitted to the Secretary of the Commission either by 
means of facsimile transmission to 301-415-1101 or by e-mail to 
[email protected] and also to the Assistant General Counsel for 
Materials Litigation and Enforcement either by means of facsimile 
transmission to 301-415-3725 or by e-mail to [email protected]. If 
a person other than the Licensee requests a hearing, that person shall 
set forth with particularity the manner in which his interest is 
adversely affected by this Order and shall address the criteria set 
forth in 10 CFR 2.714(d).
    If a hearing is requested by the Licensee or a person whose 
interest is adversely affected, the Commission will issue an Order 
designating the time and place of any hearing. If a hearing is held, 
the issue to be considered at such hearing shall be whether this Order 
should be sustained.
    In the absence of any request for a hearing, or written approval of 
an extension of time in which to request a hearing, the provisions 
specified in section IV above shall be effective and final 20 days from 
the date of this Order without further order or proceedings. If an 
extension of time for requesting a hearing has been approved, the 
provisions specified in section IV shall be final when the extension 
expires if a hearing request has not been received.

    For the Nuclear Regulatory Commission.
    Dated this 20th day of February, 2004.
R. William Borchardt,
Acting Director, Office of Nuclear Reactor Regulation.

                               Attachment
------------------------------------------------------------------------
               Facilities                           Addressee
------------------------------------------------------------------------
Beaver Valley Power Station, Units 1     Mr. L. William Pearce, Vice
 and 2, Docket Nos. 50-334 and 50-412,    President, FirstEnergy Nuclear
 License Nos. DPR-66 and NPF-73.          Operating Company, Beaver
                                          Valley Power Station, Post
                                          Office Box 4, Shippingport, PA
                                          15077.
Calvert Cliffs Nuclear Power Plant,      Mr. George Vanderheyden, Vice
 Units 1 and 2, Docket Nos. 50-317 and    President, Calvert Cliffs
 50-318, License Nos. DPR-53 and DPR-69.  Nuclear Power Plant, Inc.,
                                          Calvert Cliffs Nuclear Power
                                          Plant, 1650 Calvert Cliffs
                                          Parkway, Lusby, MD 20657-4702.
R.E. Ginna Nuclear Power Plant, Docket   Dr. Robert C. Mecredy, Vice
 No. 50-244, License No. DPR-18.          President, Nuclear Operations,
                                          Rochester Gas and Electric
                                          Corporation, 89 East Avenue,
                                          Rochester, NY 14649.
Indian Point Nuclear Generating, Units   Mr. Michael R. Kansler,
 2 and 3, Docket Nos. 50-247 and 50-      President, Entergy Nuclear
 286, License Nos. DPR-26 and DPR-64.     Operations, Inc., 440 Hamilton
                                          Avenue, White Plains, NY
                                          10601.
Millstone Power Station, Units 2 and 3,  Mr. David A. Christian, Sr.
 Docket Nos. 50-336 and 50-423, License   Vice President and Chief
 Nos. DPR-65 and NPF-49.                  Nuclear Officer, Dominion
                                          Nuclear Connecticut, Inc.,
                                          Innsbrook Technical Center,
                                          5000 Dominion Boulevard, Glen
                                          Allen, VA 23060-6711.
Salem Nuclear Generating Station, Units  Mr. Roy A. Anderson, President
 1 and 2, Docket Nos. 50-272 and 50-      & Chief Nuclear Officer, PSEG
 311, License Nos. DPR-70 and DPR-75.     Nuclear LLC-X04, Post Office
                                          Box 236, Hancocks Bridge, NJ
                                          08038.
Seabrook Station, Unit 1, Docket No. 50- Mr. Mark E. Warner, Site Vice
 443, License No. NPF-86.                 President, c/o James M.
                                          Peschel, Seabrook Station, PO
                                          Box 300, Seabrook, NH 03874.
Three Mile Island Nuclear Station, Unit  Mr. Christopher M. Crane,
 1, Docket No. 50-289, License No. DPR-   President and Chief Executive
 50.                                      Officer, AmerGen Energy
                                          Company, LLC, 4300 Winfield
                                          Road, Warrenville, IL 60555.
Catawba Nuclear Station, Units 1 and 2,  Mr. Dhiaa Jamil, Site Vice
 Docket Nos. 50-413 and 50-414, License   President, Catawba Nuclear
 Nos. NPF-35 and NPF-52.                  Station, Duke Energy
                                          Corporation, 4800 Concord
                                          Road, York, South Carolina
                                          29745-9635.
Crystal River Nuclear Power Plant,       Mr. Dale E. Young, Vice
 Docket No. 50-302, License No. DPR-72.   President, Crystal River
                                          Nuclear Plant (NA1B), Attn:
                                          Supervisor, Licensing &
                                          Regulatory Programs, 15760 W.
                                          Power Line Street, Crystal
                                          River, Florida 34428-6708.
Joseph M. Farley Nuclear Plant, Units 1  Mr. L.M. Stinson, Vice
 and 2, Docket Nos. 50-348 and 50-364,    President--Farley Project,
 License Nos. NPF-2 and NPF-8.            Southern Nuclear Operating
                                          Company, Inc., Post Office Box
                                          1295, Birmingham, Alabama
                                          35201-1295.
Shearon Harris Nuclear Power Plant,      Mr. James Scarola, Vice
 Unit 1, Docket No. 50-400, License No.   President, Shearon Harris
 NPF-63.                                  Nuclear Power Plant, Carolina
                                          Power & Light Company, Post
                                          Office Box 165, Mail Code:
                                          Zone 1, New Hill, North
                                          Carolina 27562-0165.
William B. McGuire Nuclear Station,      Mr. G.R. Peterson, Vice
 Units 1 and 2, Docket Nos. 50-369 and    President, McGuire Site, Duke
 50-370, License Nos. NPF-9 and NPF-17.   Energy Corporation, 12700
                                          Hagers Ferry Road,
                                          Huntersville, NC 28078-8985.
North Anna Power Station, Units 1 and    Mr. David A. Christian, Senior
 2, Docket Nos. 50-338 and 50-339,        Vice President--Nuclear,
 License Nos. NPF-4 and NPF-7.            Virginia Electric and Power
Surry Power Station, Units 1 and 2,       Company, 5000 Dominion Blvd.,
 Docket Nos. 50-280 and 50-281, License   Glen Allen, Virginia 23060.
 Nos. DPR-32 and DPR-37.
Oconee Nuclear Station, Units 1, 2, and  Mr. Ronald A. Jones, Vice
 3, Docket Nos. 50-269, 50-270 and 50-    President, Oconee Site, Duke
 287, License Nos. DPR-38, DPR-47 and     Energy Corporation, 7800
 DPR-55.                                  Rochester Highway, Seneca, SC
                                          29672.

[[Page 9397]]

 
H.B. Robinson Steam Electric Plant,      Mr. J.W. Moyer, Vice President,
 Unit 2, Docket No. 50-261, License No.   Carolina Power & Light
 DPR-23.                                  Company, H.B. Robinson Steam
                                          Electric Plant, Unit No. 2,
                                          3581 West Entrance Road,
                                          Hartsville, South Carolina
                                          29550.
St. Lucie Nuclear Plant, Units 1 and 2,  Mr. J.A. Stall, Senior Vice
 Docket Nos. 50-335 and 50-389, License   President, Nuclear and Chief
 Nos. DPR-67 and NPF-16.                  Nuclear Officer, Florida Power
Turkey Point Nuclear Generating           and Light Company, P.O. Box
 Station, Units 3 and 4, Docket Nos. 50-  14000, Juno Beach, Florida
 250 and 50-251, License Nos. DPR-31      33408-0420.
 and DPR-41.
Sequoyah Nuclear Plant, Units 1 and 2,   Mr. J.A. Scalice, Chief Nuclear
 Docket Nos. 50-327 and 50-328, License   Officer and Executive Vice
 Nos. DPR-77 and DPR-79.                  President, Tennessee Valley
Watts Bar Nuclear Plant, Unit 1, Docket   Authority, 6A Lookout Place,
 No. 50-390, License No. NPF-90.          1101 Market Street,
                                          Chattanooga, Tennessee 37402-
                                          2801.
Virgil C. Summer Nuclear Station, Unit   Mr. Stephen A. Byrne, Senior
 1, Docket No. 50-395, License No. NPF-   Vice President, Nuclear
 12.                                      Operations, South Carolina
                                          Electric & Gas Company, Virgil
                                          C. Summer Nuclear Station,
                                          Post Office Box 88,
                                          Jenkinsville, South Carolina
                                          29065.
Vogtle Electric Generating Plant, Units  Mr. J.T. Gasser, Vice President-
 1 and 2, Docket Nos. 50-424 and 50-      -Vogtle Project, Southern
 425, License Nos. NPF-68 and NPF-81.     Nuclear Operating Company,
                                          Inc., Post Office Box 1295,
                                          Birmingham, Alabama 35201-
                                          1295.
Brainwood Station, Units 1 and 2,        Mr. Christopher M. Crane,
 Docket Nos. STN 50-456 and STN 50-457,   President, Exelon Nuclear,
 License Nos. NPF-72 and NPF-77.          Exelon Generation Company,
Byron Station, Units 1 and 2, Docket      LLC, 4300 Winfield Road,
 Nos. STN 50-454 and STN 50-455,          Warrenville, IL 60555.
 License Nos. NPF-37 and NPF-66.
Donald C. Cook Nuclear Plant, Units 1    Mr. A. Christopher Bakken III,
 and 2, Docket Nos. 50-315 and 50-316,    Senior Vice President and
 License Nos. DPR-58 and DPR-74.          Chief Nuclear Officer, Indiana
                                          Michigan Power Company,
                                          Nuclear Generation Group, 500
                                          Circle Drive, Buchanan, MI
                                          49107.
Davis-Besse Nuclear Power Station, Unit  Mr. Lew W. Myers, Chief
 1, Docket No. 50-346, License No. NPF-   Operating Officer, FirstEnergy
 3.                                       Nuclear Operating Company,
                                          Davis-Besse Nuclear Power
                                          Station, 5501 North State
                                          Route 2, Oak Harbor, OH 43449-
                                          9760.
Kewaunee Nuclear Power Plant, Docket     Mr. Thomas Coutu, Site Vice
 No. 50-305, License No. DPR-43.          President, Kewaunee Nuclear
                                          Power Plant, Nuclear
                                          Management Company, LLC, N490
                                          State Highway 42, Kewaunee, WI
                                          54216-9511.
Palisades Plant, Docket No. 50-255,      Mr. Daniel J. Malone, Site Vice
 License No. DPR-20.                      President, Palisades Nuclear
                                          Plant, 27780 Blue Star
                                          Memorial Highway, Covert, MI
                                          49043.
Point Beach Nuclear Plant, Units 1 and   Mr. Gary Van Middlesworth,
 2, Docket Nos. 50-266 and 50-301,        Acting Site Vice President,
 License Nos. DPR-24 and DPR-27.          Point Beach Nuclear Plant,
                                          Nuclear Management Company,
                                          LLC, 6610 Nuclear Road, Two
                                          Rivers, WI 54241-9516.
Prairie Island Nuclear Generating        Mr. Joseph M. Solymossy, Site
 Plant, Units 1 and 2, Docket Nos. 50-    Vice President, Prairie Island
 282 and 50-306, License Nos. DPR-42      Nuclear Generating Plant,
 and DPR-60.                              Nuclear Management Company,
                                          LLC, 1717 Wakonade Drive East,
                                          Welch, MN 55089.
Arkansas Nuclear One, Units 1 and 2,     Mr. Jeffrey S. Forbes, Site
 Docket Nos. 50-313 and 50-368, License   Vice President, Arkansas
 Nos. DPR-51 and NPF-61.                  Nuclear One, Entergy
                                          Operations, Inc., 1448 S.R.
                                          333, Russellville, AR 72801.
Callaway Plant, Unit 1, Docket No. 50-   Mr. Garry L. Randolph, Vice
 483, License No. NPF-30.                 President and Chief Nuclear
                                          Officer, Union Electric
                                          Company, Post Office Box 620,
                                          Fulton, MO 65251.
Comanche Peak Steam Electric Station,    Mr. Michael R. Blevins, Senior
 Units 1 and 2, Docket Nos. 50-445 and    Vice President & Principal
 50-446, License Nos. NPF-87 and NPF-89.  Nuclear Officer, TXU Energy,
                                          Attn: Regulatory Affairs, P.O.
                                          Box 1002, Glen Rose, TX 76043.
Diablo Canyon Power Plant, Units 1 and   Mr. Gregory M. Rueger, Senior
 2, Docket Nos. 50-275 and 50-323,        Vice President, Generation and
 License Nos. DPR-80 and DPR-82.          Chief Nuclear Officer, Pacific
                                          Gas and Electric Company,
                                          Diablo Canyon Power Plant,
                                          P.O. Box 3, Avila Beach, CA
                                          93424.
Fort Calhoun Station, Unit 1, Docket     Mr. R.T. Ridenoure, Division
 No. 50-285, License No. DPR-40.          Manager--Nuclear Operations,
                                          Omaha Public Power District,
                                          Fort Calhoun Station FC-2-4
                                          Adm., Post Office Box 550,
                                          Fort Calhoun, NE 68023-0550.
Palo Verde Nuclear Generating Station,   Mr. Gregg R. Overbeck, Senior
 Units 1, 2 and 3, Docket Nos. STN 50-    Vice President, Nuclear,
 528, STN 50-529 and STN 50-530,          Arizona Public Service
 License Nos. NPF-41, NPF-51 and NPF-74.  Company, P.O. Box 52034,
                                          Phoenix, AZ 80572-2034.
San Onofre Nuclear Station, Units 2 and  Mr. Harold B. Ray, Executive
 3, Docket Nos. 50-361 and 50-362,        Vice President, Southern
 License Nos. NPF-10 and NPF-15.          California Edison Company, San
                                          Onofre Nuclear Generating
                                          Station, P.O. Box 128, San
                                          Clemente, CA 92674-0128.
South Texas Project Electric             Mr. James J. Sheppard,
 Generating, Station, Units 1 and 2,      President and Chief Executive
 Docket Nos. 50-498 and 50-499, License   Officer, STP Nuclear Operating
 Nos. NPF-76 and NPF-80.                  Company, South Texas Project
                                          Electric Generating Station,
                                          P.O. Box 289, Wadsworth, TX
                                          77483.
Waterford Steam Electric Generating      Mr. Joseph E. Venable, Vice
 Station, Unit 3, Docket No. 50-382,      President Operations, Entergy
 License No. NPF-38.                      Operations, Inc., 17265 River
                                          Road, Killona, LA 70066-0751.
Wolf Creek Generating Station, Unit 1,   Mr. Rick A. Muench, President
 Docket No. 50-482, License No. NPF-42.   and Chief Executive Officer,
                                          Wolf Creek Nuclear Operating
                                          Corporation, Post Office Box
                                          411, Burlington, KS 66839.
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[[Page 9398]]

[FR Doc. 04-4341 Filed 2-26-04; 8:45 am]
BILLING CODE 7590-01-C