GNRO-2012/00024, Supplemental Information Extended Power Uprate

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Supplemental Information Extended Power Uprate
ML12109A308
Person / Time
Site: Grand Gulf Entergy icon.png
Issue date: 04/18/2012
From: Krupa M
Entergy Corp, Entergy Operations
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
GNRO-2012/00024
Download: ML12109A308 (10)
v • d • e


Text

GNRO-2012/00024 April 18, 2012 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555

SUBJECT:

Supplemental Information Extended Power Uprate Grand Gulf Nuclear Station, Unit 1 Docket No. 50-416 License No. NPF-29

REFERENCES:

1.

Entergy Operations, Inc. letter to the NRC (GNRO-2010/00056),

License Amendment Request - Extended Power Uprate, September 8, 2010 (ADAMS Accession No. ML102660403)

2.

NRC letter to Entergy Operations, Inc. dated March 28, 2012, Grand Gulf Nuclear Station, Unit 1 - Issuance of Amendment Re: Power Range Neutron Monitoring System Replacement (TAC NO. ME2531)

(Amendment 188)

Dear Sir or Madam:

Entergy submitted a license amendment request (LAR) for an extended power uprate (EPU) for Grand Gulf Nuclear Station, Unit 1 (GGNS) in Reference 1. The mark-up of the Technical Specification (TS) pages included in the EPU LAR was based on the then current GGNS TSs and acknowledged that certain pages were affected by changes addressed in the proposed GGNS Power Range Neutron Monitoring System (PRNMS) LAR, which was under review at the time. Based on the recent issuance of Amendment 188 for the PRNMS (Reference 2), an update of the EPU TS mark-up for certain pages affected by the PRNMS LAR is required. provides the revised marked up pages.

This is an administrative change. Based on the approved PRNMS LAR, the revised EPU TS mark-up reflects the re-alignment of text on certain pages, includes a revision to the page numbering associated with TS Table 3.3.1.1-1, adds the title on the page 2 of Table 3.3.1.1-1, and corrects a typographical error in Function 1.a., Neutron Flux C High of Table 3.3.1.1-1 replacing C with a hyphen. No changes to the technical content originally proposed in the EPU LAR TS mark-ups are proposed.

Entergy Operations, Inc.

P. O. Box 756 Port Gibson, MS 39150 Michael A. Krupa Director, Extended Power Uprate Grand Gulf Nuclear Station Tel. (601) 437-6684

GNRO-2012/00024 Page 2 of 2 No change is needed to the no significant hazards consideration included in the initial LAR (Reference 1) as a result of the administrative revision to certain pages of the TS mark-up.

There are no new commitments in this letter.

If you have any questions or require additional information, please contact Jerry Burford at 601-368-5755.

I declare under penalty of perjury that the foregoing is true and correct. Executed on April 18, 2012.

Sincerely, MAK/FGB Attachments:

1.

Revised Technical Specification Changes (Mark-up) cc:

Mr. Elmo E. Collins, Jr.

Regional Administrator, Region IV U. S. Nuclear Regulatory Commission 612 East Lamar Blvd., Suite 400 Arlington, TX 76011-4125 NRC Senior Resident Inspector Grand Gulf Nuclear Station Port Gibson, MS 39150 U. S. Nuclear Regulatory Commission ATTN: Mr. A. B. Wang, NRR/DORL (w/2)

ATTN: ADDRESSEE ONLY ATTN: Courier Delivery Only Mail Stop OWFN/8 B1 11555 Rockville Pike Rockville, MD 20852-2378 State Health Officer Mississippi Department of Health P. O. Box 1700 Jackson, MS 39215-1700

GNRO-2012/00024 Grand Gulf Nuclear Station Extended Power Uprate Revised Technical Specification Changes (Mark-up)

RPS Instrumentation 3.3.1.1 GRAND GULF 3.3-2 Amendment No. 120, 188, ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

One or more Functions with RPS trip capability not maintained.

C.1 Restore RPS trip capability.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> D.

Required Action and associated Completion Time of Condition A, B, or C not met.

D.1 Enter the Condition referenced in Table 3.3.1.1-1 for the channel.

Immediately E.

As required by Required Action D.1 and referenced in Table 3.3.1.1-1.

E.1 Reduce THERMAL POWER to < 40% RTP.

4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> F.

As required by Required Action D.1 and referenced in Table 3.3.1.1-1.

F.1 Reduce THERMAL POWER to < 25% RTP.

4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> G.

As required by Required Action D.1 and referenced in Table 3.3.1.1-1.

G.1 Be in MODE 2.

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> H.

As required by Required Action D.1 and referenced in Table 3.3.1.1-1.

H.1 Be in MODE 3.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued) 35.4%

21.8%

RPS Instrumentation 3.3.1.1 GRAND GULF 3.3-2a Amendment No. 188, ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I.

As required by Required Action D.1 and referenced in Table 3.3.1.1-1.

I.1 Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assemblies.

Immediately J.

As required by Required Action D.1 and referenced in Table 3.3.1.1-1.

J.1 Initiate alternate method to detect and suppress thermal hydraulic instability oscillations.

AND J. 2 ------------ NOTE ------------

LCO 3.0.4 is not applicable.

Restore required channels to OPERABLE.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 120 days K.

Required Action and associated Completion Time of Condition J not met.

K.1 Reduce THERMAL POWER to < 24% RTP.

4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> 21%

RPS Instrumentation 3.3.1.1 GRAND GULF 3.3-5b Amendment No. 188, SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.20

NOTE---------------------------

1. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.
2. For Functions 2.a, 2.b, and 2.c, the APRM/OPRM channels and the 2-Out-Of-4 Voter channels are included in the CHANNEL FUNCTIONAL TEST.
3. For Functions 2.d and 2.f, the APRM/OPRM channels and the 2-Out-Of-4 Voter channels plus the flow input function, excluding the flow transmitters, are included in the CHANNEL FUNCTIONAL TEST.

Perform CHANNEL FUNCTIONAL TEST.

184 days SR 3.3.1.1.21 Perform LOGIC SYSTEM FUNCTIONAL TEST.

24 months SR 3.3.1.1.22

NOTE-----------------------

For Function 2.e, n equals 8 channels for the purpose of determining the STAGGERED TEST BASIS Frequency. Testing APRM and OPRM outputs shall alternate.

Verify the RPS RESPONSE TIME is within limits.

24 months on a STAGGERED TEST BASIS SR 3.3.1.1.23 Verify OPRM is not bypassed when APRM Simulated Thermal Power is greater than or equal to 29% RTP and recirculation drive flow is less than 60% of rated recirculation drive flow.

24 months 26%

RPS Instrumentation 3.3.1.1 GRAND GULF 3.3-6 Amendment No. 141,169,188, Table 3.3.1.1-1 (page 1 of 3)

Reactor Protection System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER TRIP SYSTEM CONDITIONS REFERENCED FROM REQUIRED ACTION D.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1.

Intermediate Range Monitors

a.

Neutron Flux C High 2

3 H

SR 3.3.1.1.1 SR 3.3.1.1.3 SR 3.3.1.1.12 SR 3.3.1.1.13 122/125 divisions of full scale 5(a) 3 I

SR 3.3.1.1.1 SR 3.3.1.1.4 SR 3.3.1.1.12 SR 3.3.1.1.13 122/125 divisions of full scale

b.

Inop 2

3 H

SR 3.3.1.1.3 SR 3.3.1.1.13 NA 5(a) 3 I

SR 3.3.1.1.4 SR 3.3.1.1.13 NA

2.

Average Power Range Monitors

a.

Neutron Flux C High, Setdown 2

3(c)

H SR 3.3.1.1.7 SR 3.3.1.1.10(d)(e)

SR 3.3.1.1.19 SR 3.3.1.1.20 20% RTP

b.

Fixed Neutron Flux C High 1

3(c)

G SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1.10(d)(e)

SR 3.3.1.1.19 SR 3.3.1.1.20 120% RTP

c.

Inop 1,2 3(c)

H SR 3.3.1.1.20 NA

d.

Flow Biased Simulated Thermal Power - High 1

3(c)

G SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1.10(d)(e)

SR 3.3.1.1.17 SR 3.3.1.1.19 SR 3.3.1.1.20 (b)

e.

2-Out-Of-4 Voter 1,2 2

H SR 3.3.1.1.19 SR 3.3.1.1.20 SR 3.3.1.1.21 SR 3.3.1.1.22 NA

f.

OPRM Upscale 24% RTP 3(c)

J SR 3.3.1.1.7 SR 3.3.1.1.10(d)(e)

SR 3.3.1.1.19 SR 3.3.1.1.20 SR 3.3.1.1.23 (f)

(continued) 4 119.3%

21%

RPS Instrumentation 3.3.1.1 GRAND GULF 3.3-6a Amendment No. 188, (a)

With any control rod withdrawn from a core cell containing one or more fuel assemblies.

(b)

Two-Loop Operation 0.65W + 62.9% RTP and 113% RTP Single-Loop Operation 0.65W + 42.3% RTP (c)

Each channel provides inputs to both trip systems.

(d)

If the as-found channel setpoint is outside its pre-defined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(e)

The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the NTSP are acceptable provided the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures to confirm channel performance. The NTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Technical Requirements Manual.

(f)

The setpoint for the OPRM Upscale Period-Based Detection algorithm is specified in the COLR.

Table 3.3.1.1-1 (page 2 of 4)

Reactor Protection System Instrumentation 0.58W + 59.1% RTP 0.58W + 37.4% RTP

RPS Instrumentation 3.3.1.1 GRAND GULF 3.3-7 Amendment No. 120 Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER TRIP SYSTEM CONDITIONS REFERENCED FROM REQUIRED ACTION D.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

3.

Reactor Vessel Steam Dome Pressure C High 1,2 2

H SR 3.3.1.1.1 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15 1079.7 psig

4.

Reactor Vessel Water Level C Low, Level 3 1,2 2

H SR 3.3.1.1.1 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15 10.8 inches

5.

Reactor Vessel Water Level C High, Level 8 25% RTP 2

F SR 3.3.1.1.1 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15 54.1 inches

6.

Main Steam Isolation Valve C Closure 1

8 G

SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.15 7% closed

7.

Drywell Pressure C High 1,2 2

H SR 3.3.1.1.1 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 1.43 psig

8.

Scram Discharge Volume Water Level C High

a.

Transmitter/Trip Unit 1,2 2

H SR 3.3.1.1.1 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 63% of full scale 5(a) 2 I

SR 3.3.1.1.1 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 63% of full scale

b.

Float Switch 1,2 2

H SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.13 65 inches 5(a) 2 I

SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.13 65 inches (continued)

(a)

With any control rod withdrawn from a core cell containing one or more fuel assemblies.

3 of 4 21.8%

RPS Instrumentation 3.3.1.1 GRAND GULF 3.3-8 Amendment No. 120 Table 3.3.1.1-1 (page 3 of 3)

Reactor Protection System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER TRIP SYSTEM CONDITIONS REFERENCED FROM REQUIRED ACTION D.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

9.

Turbine Stop Valve Closure, Trip Oil Pressure C Low 40% RTP 4

E SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 37 psig

10.

Turbine Control Valve Fast Closure, Trip Oil Pressure C Low 40% RTP 2

E SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 42 psig

11.

Reactor Mode Switch C Shutdown Position 1,2 2

H SR 3.3.1.1.11 SR 3.3.1.1.13 NA 5(a) 2 I

SR 3.3.1.1.11 SR 3.3.1.1.13 NA

12.

Manual Scram 1,2 2

H SR 3.3.1.1.4 SR 3.3.1.1.13 NA 5(a) 2 I

SR 3.3.1.1.4 SR 3.3.1.1.13 NA (a)

With any control rod withdrawn from a core cell containing one or more fuel assemblies.

4 of 4 35.4%

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