IEEE Std 387-2017 Technical Basis Matrix (Master) Revision...

IEEE Std 387-2017 Technical Basis Matrix (Master)

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Sub Clause,

Table, Figure,

or Annex

Description of Change

Technical Basis (Include Technical References)

1.3.1.b)2) &

************

Clause 2

************

Figure 1

************

4.5.1.6

************

Table 2

************

Annex B,

Table B.2

EDG Breaker to be included in scope:

1. Added “The diesel generator output

breaker”

2. Added the following references to

Annex E (Bibliography):

IEEE C37.010 – “IEEE Application

Guide for AC High-Voltage Circuit

Breakers Rated on a Symmetrical

Basis”

IEEE C37.06-2009 – “IEEE

Standard for AC High-Voltage

Circuit Breakers Rated on a

Symmetrical Current Basis--

Preferred Ratings and Related

Required Capabilities for Voltages

Above 1000 V”

IEEE C37.09 – “IEEE Standard

Test Procedure for AC High-

Voltage Circuit Breakers Rated on

a Symmetrical Current Basis”

IEEE C37.13 – “IEEE Standard for

Low-Voltage AC Power Circuit

Breakers Used in Enclosures”

3. Revised Figure 1 to show EDG breaker

inside the scope line.

4. Added new sub-clause 4.5.1.6 echoing

“Technical Basis” from right hand

column.

5. Added “Circuit Breaker” to Table 2

6. Table B.2

The Emergency Diesel Generator (EDG) output breaker is to

be included in IEEE Std 387. Technical Basis:

_________________________________________________

The generator output circuit breaker is necessary to support

the testing requirements delineated in this standard where the

EDG must be connected to the Class 1E bus to accomplish

testing as required/defined in Sub-clause 7.4 (Periodic

testing) and Sub-clause 7.5 (Test descriptions). For example:

1. Energize the Class 1E bus to support EDG loading

tests

2. Energize the isolated bus for Loss of Offsite Power

(LOOP) and LOOP/Safety Injection Actuation

Signal (SIAS) and shutdown testing

3. Restore the diesel loads back to preferred power

supply

Circuit breaker design and testing features should follow the

IEEE C37 standards as identified in Annex E (Bibliography),

where appropriate.

_________________________________________________

IEEE Std 387 will not provide design and testing

requirements. Instead IEEE Std 387 will provide roadmap to

existing IEEE standards (see Annex E (Bibliography)):

IEEE C37.010 – IEEE Application Guide for AC

High-Voltage Circuit Breakers Rated on a

Symmetrical Basis

IEEE C37.06-2009 - IEEE Standard for AC High-

Voltage Circuit Breakers Rated on a Symmetrical

Current Basis--Preferred Ratings and Related

Required Capabilities for Voltages Above 1000 V

IEEE C37.09 – IEEE Standard Test Procedure for

AC High-Voltage Circuit Breakers Rated on a

Symmetrical Current Basis

IEEE C37.13 - IEEE Standard for Low-Voltage

AC Power Circuit Breakers Used in Enclosures

Figure 1

************

1.3.1.a)5)

************

4.5.1.7

1. Scope Diagram: EDG Fuel Oil Storage

and Supply system added to Scope.

2. Added Fuel Oil Storage and Supply

System to systems in Section 1.3.1.a)5),

and deleted from Section 1.1.3.

3. Added 4.5.1.7 to reference ANSI

standard for system requirements.

2016-1-25 Meeting:

The EDG Fuel Oil Storage and Supply System is included in

the boundary of the EDG system because this subsystem is

needed for the EDG to perform its function. The engine fuel

oil system including the day tank, typically only provides a

few hours of fuel immediately available to the EDG. The

fuel oil storage tanks, the fuel oil transfer pumps, and its

associated controls and piping are needed to replenish the

day tank so the EDG can continue to fulfill its mission.

Specific requirements for the fuel oil system regarding tank

capacity are provided in ANS 59.51-1989, Fuel Oil Systems

for Emergency Diesel Generators. Note – it is not expected

that EDG suppliers will be responsible for providing fuel oil

storage tanks for the EDGs as part of their scope of work.


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1.3.1.d

1.4.a)3)

4.5.2.4

7.5.16

These sub-clauses have been added/updated to

address EDGs with dedicated batteries for

sizing, installation, testing, and maintenance

Some nuclear power plants have (and will continue to

design) EDGs with dedicated batteries as opposed to using

125Vdc station batteries for control power. These include

references to IEEE Std 450, 485, 1115, and 1106.

3.15 Definitions – Additional EDG failure

definitions from NEI 99-02, Regulatory

Assessment Performance Indicator Guideline,

such as Failure to Start, Failure to Load, and

Failure to Run should not be included.

The working group concluded that these definitions should

not be added to the standard. The standard now has clear

guidance on start failures and load run failures (including

exceptions) that focus on failures to meet the EDG design

function. Regarding function, the guidance in NEI 99-02 has

been reviewed and is consistent with the guidance in IEEE

Std 387. The new NEI definitions are provided more for

plant PRA and timing than function (i.e. when the EDG

failed), which has no place in this standard. These

definitions have also been revised periodically. IEEE Std

387 is recognized and adopted as an international standard

that can be used as a reference guide for portions of reactor

oversight programs related to EDGs, but should not be

revised to include every new definition that arises from these

programs.

3.15.5 Definition: Start Time: The elapsed time

between receipt of an emergency start signal

and achieving voltage and frequency for

breaker closure to energize required loads.

The intent is to convey the concept that the first instant

where the EDG output breaker can close is the start time

termination point. This point is difficult to define since plants

do not all share the same breaker logic. In some cases the

breaker can close and the load can be applied during the

ramp up to speed and voltage before one/both have yet to

achieve within 10% of their nominal values, while still

starting and accelerating loads as necessary. In other cases

the breaker control logic includes hard permissives for

frequency, voltage, or both frequency and voltage.

This applies to sub-clause 7.2.1.1

4.1.2.c. Clarification on light load sub-clause 4.1.2.c.

The following text was added: "Provisions to

enable successful light or no-load operation

may be provided by the manufacturer."

This is a design criteria that engines must be able to run at

low and no load. The following text was added: "Provisions

to enable successful light or no-load operation may be

provided by the manufacturer." Engines operate most

efficiently at design load, however, unique operating

requirements in certain applications require light or no load

operation. An issue with light or no load operation is lower

pressure in the cylinder, which leads to less pressure acting

on the back of the piston rings to seal the cylinder, which can

allow excess lube oil into the combustion space and

combined with unburnt fuel can enter the exhaust. Some

EDG manufacturers provide guidance that requires operation

of the EDG at higher loads to clean out the exhaust following

extended operation at no or low load. Section 4.2.2.a of this

document (4.2 Ratings, 4.2.2 Operation) – provides guidance

on low load operation that has been approved by the working

groups (including OEM representatives) for previous

versions of this document,


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4.1.2.e.1. No change to standard: Technical Basis

developed in support of sub-clause 4.1.2.e.1,

particularly with respect to EDGs that carry

only one large connected load. Sub-clause

4.1.2.e.1 is as follows:

“The diesel generator shall be designed such

that the frequency will not decrease, at any

time during the loading sequence, to less than

95% of nominal and the voltage will not

decrease to less than 75% of nominal. (A

larger decrease in voltage and frequency may

be justified for a diesel generator that carries

only one large connected load.)”

Frequency and Voltage variations exceeding minimum

values due to load sequencing: Few existing licensees have

requested exemptions from RG 1.9 Rev.4 requirements

(Section C, clause 1.4) for voltage/frequency dips and

recovery time. Random sampling of 10 HPCS DGs resulted

in 1 request for exemption. Most of the exemption requests

were from licensees with older DG models and little or no

margin between postulated loads and continuous rating. The

intent of restricting voltage and frequency perturbations and

recovery times is to provide a level of assurance (on a

generic basis) that (i) loads that are operating, continue to

operate without stalling or slowing down to the extent that

the next load is adversely impacted and (ii) have confidence

that large loads can start without adversely impacted DG and

load response time assumed in accident analyses. With new

designs in governor controls for maintaining frequency and

better excitation controls and voltage regulators along with

adequately sized DGs, the requirements in RG 1.9 Section C,

1.4 are not an issue any more. So going forward, there is no

reason to include any further exemptions to the requirement.

The existing verbiage (HPCS only) is acceptable.

For further information, see INL/EXT-16-37929 “System

Study: High Pressure Core Spray 1998-2014”, Schroeder,

December 2015. Areas of interest are:

Chapter 7 “HPCS System Description” which provides

a good overview of the system.

Figure 4: Simplified schematic of the HPCS

system. In some BWR configurations, there is a

Division III 4160V power board with offsite power and

a dedicated DG. The largest load is the HPCS pump

motor followed by the service water motor. The HPCS

valves are also powered from this bus.

4.1.2.f Provisions for Operator/Attendant actions.

The unit shall be equipped with provision for

maintenance actions while carry the Design

Load as defined in 4.1.2.d, above.

Maintenance actions include replenishment of

fluids and duplex filter changes.

The intent of this item is to assure that expected actions

during an extended EDG mission are able to be

accomplished without requiring shutdown or other action

impacting the ability to respond as needed. Example of

expected maintenance are: lubrication replenishment and fuel

filter changes. Accordingly, provisions shall be provided to

facilitate these expected actions while the EDG is running in

support of an actual demand without inhibiting EDG

operation. One example provision is to provide duplex fuel

filter assemblies that allow for the filter changes while the

EDG is running.

It is entirely reasonable and expected to perform oil and

coolant additions during an extended EDG run. Routine

inventory loss through consumption (i.e., engine lube oil.)


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4.4

Table 1

Item 1

Basis - Section 4.4, item 1 emphasizes the

importance of not inadvertently introducing

common-mode or comment cause failures in

the design and application of standby power

supplies. The original text originally

referenced only common mode. We are

adding Common Cause because INPO SOER

03-01, Recommendation 1, addresses

common-cause as well as common-mode

failures.

INPO SOER-03-01 Recommendation 1: A disturbing aspect

of some events analyzed for this WANO SOER is the

number of events where diverse emergency power systems

were actually (or with credible potential) affected by

common mode or common-cause failures. Design of

emergency power systems are based on the philosophy of

independent redundant capability, but analysis shows that

often, faults or mistakes made in design modification, or

operating configurations for one train of emergency power

adversely affect other trains as well.

4.5.4 The diesel-generator unit shall be

automatically tripped on an engine overspeed

and generator differential

overcurrent. Protective features, other than

engine overspeed and generator differential

current, shall be the following:

a) Blocked from automatically tripping the

diesel-generator unit during an accident

condition safety injection actuation signal

(SIAS) and combined SIAS with loss of

offsite power (LOOP) and shall be

annunciated in the plant control room, or

b) If protective features other than engine

overspeed and generator differential

current are retained during accident

conditions, two or more independent

measurements of each of these parameters

with coincident trip logic shall be

provided. The design of the coincident trip

logic circuitry shall provide alarm for each

individual sensor initiation and shall

include the capability to indicate

individual sensor trips. All protective

devices shall remain effective during the

diesel-generator unit testing, and during

operation in non-accident conditions.

Other periodic tests that demonstrate

diesel generator system response under

simulated design-basis events shall include

protective trip bypass (SIAS and

SIAS/LOOP).

c) If protective features are bypassed during

accident conditions, the circuitry should

include the capability to perform the

following tasks:

1) Test the status and operability of the

bypass circuits,

2) Trigger alarms in the control room for

abnormal values of all bypass

parameters (common trouble alarms

may be used), and

3) Manually reset the trip bypass

function.

i) Manual reset ensures bypassed

trips are not inadvertently re-

enabled when diesel-generator is in

accident mode

First Paragraph - Revised to clarify that two or more

measurements are not needed for overspeed and generator

differential. Redundancy is not provided for these important

trips.

Additional technical modifications made to be consistent

with RG 1.9, R4.

This revision to emphasize preventing EDG inadvertent non-

essential trip restoration when EDG is performing its

accident mission and to ensure these trips are restored to

protect the EDG during non-accident conditions (e.g.,

testing).


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ii) To ensure asset protection is

restored when the EDG is in the

test mode or non-accident mode.

4.5.4 Clarification regarding if LOOP should be

included in referenced tests that should

include trip bypass.

The tests listed are specifically from Regulatory Guide 1.9,

Revision 4. The NRC refers to IEEE Std 387 4.5.4.b which

states “All protective devices shall remain effective during

the diesel-generator unit testing, and during operation in non-

accident conditions, inferring that the protective devices

should be in place for a LOOP. Working group discussion

indicated that many plant designs do not bypass protective

trips during a LOOP and due to potential extended run time,

some expressed a desire to have this protection active. A trip

may prevent a catastrophic failure of the EDG, and if the trip

is inadvertent, it is expected that the EDG can be brought

back to service in a quick manner. However, standard will

remain the same as the IEEE Std 387-1995 and US NRC

Regulatory Guide 1.9 (i.e., trip bypass for SIAS and

SIAS/LOOP, only).

4.5.4.a Sponsor & Recirculation Ballot Comment on

EDG ground fault protection

See Attachment #1

6.5.1

Change wording of sub-clause 6.5.1 to

(change in italics):

A separate preventive maintenance,

inspection, testing, and monitoring program

(see also 6.5.2) shall be established for the

diesel-generator unit and all supporting

systems based on the manufacturer’s

recommendations, or other alternative

program with sufficient technical basis for

EDGs used in nuclear standby applications.

These preventive maintenance, inspection,

testing, and monitoring recommendations may

be based on condition, operating hours, fixed

time intervals, industry operating experience,

or a combination of any of these. Programs

shall include, as a minimum, specific

procedures for each portion of the unit as

follows:

ALSO ADDED:

Monitoring, to include the following:

Diesel generator monitoring practices should

follow those, similar to ASME OM-2015,

Operation and Maintenance of Nuclear Power

Plants (Part 16, Performance Testing and

Monitoring of Standby Diesel Generator

Systems in Light-Water Reactor Power

Plants)

Technical Justification:

Many of the maintenance programs from diesel engine

manufacturers are based on the assumption that the diesel is

not used in a standby application, but rather operated

continuously. Over the last 20 years, the nuclear power

industry in the US has developed significant experience in

operating and maintaining diesel engines used in nuclear

standby applications. This experience and knowledge of

operation, testing, and maintenance has been captured within

maintenance programs developed by Emergency Diesel

Generator Owners Groups. These programs are well

established within the industry, recognized by the regulators

and the industry as being the basis for preventive

maintenance, inspection, and testing programs at individual

plants. In many cases, the diesel engine manufacturers also

review and contribute to these programs. These programs

have proven effective in maintaining the reliability of EDGs.

The revised standard makes provision for use of these

programs as the basis for an adequate preventive

maintenance, inspection, and testing programs.

Since the last (1995) revision of this standard, the

requirement of basing maintenance on manufacturer’s

recommendations has been removed from many US plant

Technical Specifications. Incorporating this revision will

allow non-US plants greater flexibility to improve their

maintenance programs and thereby improve overall EDG

reliability.

7.1 Table 3 – For outage / 2 year testing, should

allowance be provided for risk based

surveillance frequencies

The Working Group concluded outage / 2 year testing is

sufficient and that exceptions based on risk analysis (or

PRA) should not be included in this standard. The working

group determined that this standard sets appropriate world-

wide guidance on testing intervals that prove that the EDG

can reliably perform its safety function. The recommended


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intervals in this document have been proven to meet this

purpose over an extended period of time. Plants that wish to

take exception to this standard can do so with appropriate

technical bases and regulatory approvals, which may differ

in worldwide applications.

7.4.1 Added to 7.4.1 (Periodic testing – General) to

caution against overloading EDG during

testing:

For the purposes of periodic testing, the EDG

shall not be operated greater than the OEM’s

established continuous ratings, other than for

the provisions regarding loading to the short

term ratings in the endurance and load test

(see 7.5.9).

The change will help ensure the EDG is not operated above

its design ratings for routine testing, thus supporting long

term reliability of the machine.

Operating Experience: one plant changed technical

specifications to test at greater than maximum design load

(or greater than 110% load) for the entire 24-hour endurance

run. After the first test, wear metals in the engine increased

substantially (internal engine design changes were made to

prevent further degradation). Testing to design load

conditions is outside of current regulatory guidance (RG 1.9,

R4, and IEEE Std 387-1995). OEMs involved do not

recommended extended routine periodic testing at overload

conditions – other than the two hours at the short term rating.

7.5.8 & 7.5.7 Full Load Reject Power Factor Technical

Requirements:

o Sub-clause 7.5.8: Change from::

Demonstrate the diesel-generator unit’s

capability to reject a load equal to 90-100%

of the design load and verify that the unit

will not trip on overspeed” to

o Demonstrate the diesel-generator unit’s

capability to reject a load equal to 90-100%

of the design load at a power factor selected

to minimize generator and exciter

degradation, and verify that the unit will not

trip on overspeed.

1. Full Load Reject: This is primarily a governor performance

challenge to ensure overspeed is prevented. Voltage

regulators have no similar overvoltage protection and will

not shutdown (only momentarily result in full firing of the

silicon controlled rectifiers (SCR)). However, if full power

factor is to be required during this test, Tech Specs should

not specify a voltage limit (as it may be influenced by high

bus voltages during an outage and a test limitation).

Instead, no voltage regulator shutdown or adverse

performance may be specified as an acceptance criteria if it

is still desired to perform full power factor for testing.

2. Partial Load Reject (Sub-clause 7.5.7): Full power factor

for the largest design load reject should be maintained; as

it supports demonstrating voltage regulator dynamic

response to accident loads sequencing on and off.

7.5.9 Endurance Run and Load Test duration

change from 8 hours to 24 hours.

Technical Basis:

NRC Inspection Manual

Temporary Instruction 2515/176

“Emergency Diesel Generator Technical Specification

Surveillance Requirements Regarding Endurance Runs and

Margin Testing”, dated 5/16/08.

NRC Memorandum to Patrick Hiland, Director from George

A. Wilson, Chief, Subject: “EMERGENCY DIESEL

GENERATOR TECHNICAL SPECIFICATIONS

SURVEILLANCE REQUIREMENTS REGARDING

ENDURANCE AND MARGIN TESTING: SUMMARY

REPORT”, December 10, 2009.

Per Discussion and Recommendation following Questions

2.a and 2.b (page 5) that in some cases, plants with 24-hour

endurance runs identified degraded component performance

resulting from EDG maintenance or system modification

deficiencies that would not have been identified by plants

with TS testing requirements of 8 hours (or less). Five (5)

examples are cited in the NRC Memorandum.

7.5.9 Endurance Run Power Factor Technical

Requirements

Full power factor for 24 hour endurance run should not be an

expectation. A short portion of the test should include full

power factor to demonstrate the voltage regulator can


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achieve the full range necessary to meet the required power

factor (e.g., 0.8), but it is not an endurance requirement.

7.5.9 Additional regarding sequence of 2 hour short

time rating and the 22 hour continuous rating.

Regarding comments on endurance runs and the two hour

operation at 110% loading condition. There is working group

consensus agreement that it is easier and better from operator

perspective to perform test immediately after starting the DG

for the 24 hour load run. Based on experience, one shift (day

shift) would make all the arrangements (satisfy the

prerequisites) for the 24 hour run. After turnover and

completion of operator rounds (checks and surveillances),

the new shift (midnight) would start and run the DG. Since

this team (shift) had just started, the operators knew that they

had approximately 10 hours of DG operation to solve any

problems. The start, the DG synchronization process, and

gradual loading to 110% was generally the most challenging

aspects of this surveillance and these could be accomplished

within one shift.

We expect the 110% DG rating to be ‘challenged’ at the

onset of an event when (plant) primary system and

secondary system pressures and flows ‘allow’ the pumps to

operate at run out conditions (e.g., 110% of nominal rating).

We expect conditions to stabilize within two hours when

‘steady state’ operating conditions are achieved. So 110%

DG load run at the beginning of the surveillance is in

alignment with postulated operational demand or load

profile.

From Operating Experience perspective:

We know that a significant portion of DG failures can be

attributed to maintenance/repair activities. Some of the issues

can be identified within a few minutes of DG operation after

maintenance activities have been completed and the DG

started to demonstrate operability. However, based on a

survey that the NRC conducted a few years ago, it was

found that a lot of failures occurred after the DG had

operated for some time (typically more than 10 to 12 hours)

and were related to component failure due to vibrations, heat,

fatigue, improper fitting, alignment, etc. Hence, a 110% load

run towards the end of the 24 hour surveillance may be

appropriate to demonstrate that the higher stresses at any

given time can be withstood.

For consistency with most nuclear power plants, it is

recommended that the 110% portion of the surveillance

requirement (SR) at the start of the test run is kept. Since the

SR is performed with a slow start, the DG allowed to reach

equilibrium conditions and the loading increased at gradual

level, we should not expect any difference in wear and tear

(affecting reliability) compared to testing at a different time

during the 24 hour run.

7.5.12 Added:

“…and those trips retained with coincident

logic are not bypassed.”

Supports clause 4.5.4 and US NRC RG 1.9 R4, Section

2.2.11.

7.5.13

Protective-trip verification test (new):

The tests should verify that the critical

protective trips perform their intended function

2016-1-25 Meeting:

This new test was added to ensure that these trips are

functionally checked or tested to protect the critical asset

(EDG). It was made a separate test from 7.5.12 because it


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and are not bypassed during emergency

conditions.

was determined it was not necessary to perform this test at

the same time the trip bypass test is performed.

Note: US NRC R.G. 1.9, R4 had this a similar protective-trip

bypass test in paragraph (2.2.11) of what is equivalent to

IEEE Std 387 sub-clause 7.5.12. However, this test was also

not a critical trip verification test, but a protective device trip

bypass test.

Annex D New Annex D “influence of voltage

regulating equipment on emergency diesel

generator (EDG) surveillance testing”

Attachments #2 and #3 are included with the Technical Basis

Matrix:

1) PSEG White Paper to IEEE SC-4 WG 4.2 (Std

P387) – DRAFT (Attachment #2).

2) South Texas Procedure: 0PSP03-DG-0016

“Standby Diesel 11(21) Twenty-Four Hour Load

Test”, Rev. 38 (Attachment #3).

General Should EDG mission time be addressed in this

document?

The Working Group determined that EDG mission time

should not be included in this standard due to the following

reasons:

1) EDG mission time for some plants is established

by accident analysis in their licensing basis,

2) EDG mission time should be based on plant

design and established by the nuclear vendor’s

analysis vs. a common mission for all in an

industry standard, and

3) This is an international standard that can be

referenced or applicable to numerous designs and

plant configurations, that may call for different

EDG mission times.

It was also discussed that establishing a common EDG

mission time such as 30 days would raise several other issues

that may need to be addressed by site licensing basis and risk

analysis, such as how long should the EDG operate without

operator attention and action, Based on these complications

and the uniqueness of EDG to each plant design, the working

group determined that mission time should not be addressed

in this standard.

Attachment 1 EDG Ground Protection 4.5.4.a

Page 1 of 4

IEEE P387 Sponsor Ballot Original Comment (1/11/2017): 4.5.4.a), page 15, line 32 Blocking of protective features from tripping the DG during SIAS and SIAS + LOOP has very serious consequences for the “DG Ground Fault Protection”. If the DG ground fault components have not been adequately designed to perform under the blocking conditions the DG may fail catastrophically! The failure of the DG becomes imminent with time and a direct consequence of the blocking. If the DG ground fault trip has been blocked to prevent tripping of the DG, this is typically accomplished by blocking the ground fault trip signal to the DG circuit breaker; however, this does not remove the ground fault but just the trip function. As long as the ground fault exists, high magnitude ground fault current from the DG neutral will persist and flow to ground through DG ground fault resistor and its connecting cable. Unless these components have been intentionally designed for continuous duty versus short-time duty, the resistor, the cable, relays, or the generator windings will fail catastrophically. If the resistor or the neutral cable fails first, the once grounded system will revert to an ungrounded system; however, the accompanying smoke and fire will likely initiate a manual trip of the EDG. If the generator windings, initially with a ground fault, could develop rapidly into a full fledged three-phase fault necessitating action by the differential protective trip. One has to question the nonsensical logic of blocking of the DG Ground Fault Protection. No extended performance or reliability is achieved by blocking the ground fault protection as the generator could be taken off-line momentarily by actuation of the generator differential trip function. Blocking of protective features as outlined in Section 4.5.4.a) should be deleted in its entirety as it represents flawed logic with no technical basis. Section 4.5.4.b) provides an acceptable alternative for all DG protective features for minimizing spurious operation.


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IEEE/PES/NPEC SC-4 Working Group 4.2 Ballot Response:

During the design of the current vintage of operating nuclear plants, it was agreed that the

emergency diesel generator is the last line of defense for providing AC emergency power

to the emergency safety feature (ESF) equipment to protect the reactor and the potential

radioactive release to the public. When the emergency diesel generator is actively

providing power during a design basis accident, it was determined that providing power

to ESF loads was such a critical function that risking running the EDG to failure is more

important to nuclear safety than protecting the generator or engine for malfunctions that

over time can cause damage to the EDG. Only the protective functions for differential

current and overspeed were left in place to trip since these failures will lead to immediate

catastrophic failure of the engine or generator.

Emergency diesel generators can be designed with high impedance neutral grounding or

ungrounded neutral. With this configuration, the generator can run for an extended period

of time with a single line to ground fault before the machine will be damaged to the point

to prevent supply of power to the ESF motors required to mitigate the impact of a design

basis accident.

IEEE 387 Subclause 4.5.4.b already provides the provision that if other protective

features (e.g., EDG ground protection) are retained during accident conditions, two or

more independent measurements of each of these parameters with coincident trip logic

shall be provided.

Therefore, there will be no change to the standard.


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IEEE P387 Recirculation Ballot Original Comment (06/21/2017): SubClause 4.5.4.a (Line 4): Perhaps the WG misunderstood my comment, I was not calling for outright removal of

the blocking of the trip, but in the event that blocking is adopted (ie. no instantaneous

trip) then the rest of the ground fault protection system must also be modified to

accommodate continuous operation of all its associated components such as the cables,

relays, and resistors. Failing this it is clear that IEEE 387 has knowingly introduced a

design deficiency unless additional clarification is provided in 4.5.4.(a) for user

understanding of the implications of the blocking. As you well know a failure of a system

from a design deficiency must be assumed prior to applying the Single Failure Criterion;

therefore, the EDG as designed per IEEE 387 does not meet the single failure criterion

either!!

IEEE/PES/NPEC SC-4 Working Group 4.2 Ballot Response:

WG 4.2 respectively disagrees that IEEE 387 has introduced a design deficiency

regarding ground protection. The WG position is that bypassing an EDG trip (i.e.

Ground Relay) during a design basis accident is based upon a design philosophy stated in

the previous ballot comment response*. The position is that a ground fault is a single

failure of the EDG and its associated train. Since a single failure may not result in

immediate loss of one safety-related train, any continued operation of the EDG and its

associated train accomplishes this defense in depth design philosophy until it is tripped

on other protection or manually shutdown. The design scope of the EDG in this standard

is not intending to design the support systems to allow continuous operation with a single

failure.

As stated in the previous ballot comment response*, IEEE 387 Subclause 4.5.4.b already

provides the provision that if other protective features (e.g., EDG ground protection) are

retained during accident conditions, two or more independent measurements of each of

these parameters with coincident trip logic shall be provided.

Based on the above, Working Group 4.2 retains the position that the standard does not

require revision.

*IEEE/PES/NPEC SC-4 Working Group 4.2 Previous Ballot Response):

During the design of the current vintage of operating nuclear plants, it was agreed that the

emergency diesel generator is the last line of defense for providing AC emergency power

to the emergency safety feature (ESF) equipment to protect the reactor and the potential

radioactive release to the public. When the emergency diesel generator is actively

providing power during a design basis accident, it was determined that providing power

to ESF loads was such a critical function that risking running the EDG to failure is more

important to nuclear safety than protecting the generator or engine for malfunctions that

over time can cause damage to the EDG. Only the protective functions for differential


Page 4 of 4

current and overspeed were left in place to trip since these failures will lead to immediate

catastrophic failure of the engine or generator.

Emergency diesel generators can be designed with high impedance neutral grounding or

ungrounded neutral. With this configuration, the generator can run for an extended period

of time with a single line to ground fault before the machine will be damaged to the point

to prevent supply of power to the ESF motors required to mitigate the impact of a design

basis accident.

IEEE 387 Subclause 4.5.4.b already provides the provision that if other protective

features (e.g., EDG ground protection) are retained during accident conditions, two or

more independent measurements of each of these parameters with coincident trip logic

shall be provided.

Therefore, there will be no change to the standard.

To: IEEE SC4 WG 4.2 (Std P387)

Purpose:

This paper describes the effects on Class 1E bus voltages during Emergency Diesel

Generator synchronized surveillance testing for stations equipped with Load Tap

Changers.

Things to consider:

Location of Load Tap Changer and Sensing Input:

Load Tap Changers can be installed on the High Voltage or Low Voltage windings of

station power transformers. Because these are Non1E control devices, sensing inputs are

typically provided from a PT directly at the secondary of the transformer or a PT from

Non1E bus connected to the regulated source. In both cases voltage drop must be

considered in evaluating the choice of LTC setpoints.

Control Band and Time Delay:

Typical control band settings provide a bandwidth of greater than 1 tap on either side of

the bandcenter (regulated setpoint) to avoid unnecessary tap changer hunting. Typical

LTC delay times are 30 second nominal with 12 seconds per tap once the LTC is

activated. Settings may differ from manufacturer typical based on plant design or desired

level of voltage regulation.

Diesel Synchronization:

When an EDG is manually synchronized, EDG terminal voltage must be slightly higher

than the receiving bus to avoid any undesired diesel perturbations. Once synchronized the

diesel will gradually pick up load up to its approximate continuous loading, and supply

reactive power (lagging operation) to avoid unexpected low voltage perturbation on

Class 1E buses.

Typical behavior after Synchronization:

As the EDG is loaded from nominal to full load and Var loading is varied from nominal

to surveillance levels, the local Class 1E voltage will increase.

Owner

Text Box

Attachment #2

The following plot shows Class 1E Bus Voltage behavior for an EDG Surveillance run performed at Hope Creek Generating Station

on 5/6/2011.

The Load Tap Changer and Controller are configured as follows:

Transformer Ratio: 13800/4160

Tap 15% Low, +5% High

#Tap – 32, 0.625% per tap (26 V of a 4160 V Base)

Band Center: 4232

Band Width: 41974267

1

2 3

4

5

6

Discussion:

Section 1 – Class 1E Bus voltage is approximately 4229 V prior to synchronization of the

EDG.

Section 2 – EDG is synchronized and bus voltage immediately increases by

approximately 20 V. Upon synchronization Station procedures direct the EDG to load

initially to between 500 kW and adjust kVar output between 100 and 500. Feeder

amperage decreases by approximately 500 KW.

Section 3 – Station procedure has the EDG gradually pickup load in 500 KW increments

resting from 35 minutes at every 1000 kW added. The input to the load tap changer

controller comes from a Non1E 4160 bus connected to the same transformer.

Section 4 – As the EDG picks up load, the regulating transformer is offloaded. Once

voltage on the bus is approximately equal to the upper band setting a step change in

voltage decrease is observed approximately equal to 1 tap (4260 V to 4230 V).

Section 5 – Immediately after the EDG is loaded to its final nameplate rating, station

procedure increases kVar output to approximately 1000 resulting in the final steady state

voltage increase, which is only 15 V, less than a single tap and within the LTC deadband.

Section 6 – EDG is in steady state loaded operation. The grid supply is stable and no

additional tap changes occur through unit unload.

SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION D0527 STI 33736037 0PSP03-DG-0016 Rev. 38 Page 1 of 99

Standby Diesel 11(21) Twenty-Four Hour Load Test

Quality Safety-Related Usage: IN HAND Effective Date: 08/05/2013

R. A. Smith Dustin Janak Crew 1E Operations

PREPARER TECHNICAL USER COGNIZANT DEPT. Table of Contents Page

Procedure Performance Data Sheet............................................................................................................. 2

1.0 Purpose and Scope .......................................................................................................................... 5

2.0 Responsibilities ............................................................................................................................... 7

3.0 Precautions and Notes ..................................................................................................................... 8

4.0 Prerequisites .................................................................................................................................. 15

5.0 Procedure....................................................................................................................................... 22

5.1 Preparation .......................................................................................................................... 22

5.2 DG Prestart Inspection ........................................................................................................ 25

5.3 DG Auto Start ESF Actuation............................................................................................. 29

5.4 DG Test Mode Override...................................................................................................... 34

5.5 DG One Hour Load Test ..................................................................................................... 36

5.6 DG 5500 KW Load Reject.................................................................................................. 38

5.7 DG Twenty-Four Hour Load Test....................................................................................... 41

5.8 DG Hot Restart Test............................................................................................................ 51

5.9 DG Loading......................................................................................................................... 57

5.10 DG Unloading ..................................................................................................................... 62

5.11 DG Shutdown...................................................................................................................... 65

5.12 DG Post Run Checklist ....................................................................................................... 66

5.13 DGFOST Accumulated Water Check/Removal ................................................................. 73

5.14 Restoration and Documentation.......................................................................................... 76

6.0 Acceptance Criteria....................................................................................................................... 83

7.0 References ..................................................................................................................................... 85

8.0 Support Documents....................................................................................................................... 92

Addendum 1, DG 11(21) Recorder Installation/Removal ............................................................ 93

Addendum 2, Technical Specification Surveillance Requirements Satisfied Table..................... 99

Owner

Text Box

Attachment #3

0PSP03-DG-0016 Rev. 38 Page 2 of 99


This procedure, when complete, SHALL be retained for at least 5 years.

Procedure Performance Data Sheet

Unit Number:

Work Activity Number: -ST:

Technical Specification Reference: 4.3.2.1.1.a.4, 4.3.2.1.1.c.7, 4.3.2.2.2.a.9, 4.3.2.2.3.a.9, 4.3.2.2.5.a.9, 4.8.1.1.2.a.1, 4.8.1.1.2.a.2,

4.8.1.1.2.a.3, 4.8.1.1.2.a.4, 4.8.1.1.2.b, 4.8.1.1.2.e.3, 4.8.1.1.2.e.5, 4.8.1.1.2.e.7, 4.8.1.1.2.e.10, and 4.8.1.2 Test Interval:

Refueling

Test Performance Allowed in Plant Modes:

1, 2, 3, 4, 5, 6 or Defueled

Train Reference:

A Reason for Test:

Periodic Surveillance Test For Surveillance Credit Maintenance Work Package # Not for Surveillance Credit Other

Radiation Work Permit No.: N/A

Fire Hazard Evaluation No.: N/A

Equipment Clearance No.: N/A

Administrative Approval to Perform Test:

Approved By: Shift Manager Date Time Test Results Review: Technical Specification Surveillance Requirements Satisfied Monthly 4.8.1.1.2.a.1 4.8.1.1.2.a.4 4.8.1.1.2.a.2 4.8.1.1.2.b 4.8.1.1.2.a.3 18 Month at power 4.3.2.1.1.c.7 4.3.2.1.1.a.4 4.3.2.2.5.a.9 4.3.2.2.2.a.9 4.8.1.1.2.e.7 4.3.2.2.3.a.9 18 Month Shutdown 4.8.1.1.2.e.3 4.8.1.1.2.e.10 4.8.1.1.2.e.5

Acceptable - All Data within Acceptance Criteria for Sections that were performed Unacceptable - Any Data NOT within Acceptance Criteria (explain in Remarks) Reviewed By: Test Coordinator Date Time





Plant Operations Review: All Data within Acceptance Criteria? Yes No DG 11(21) Operable? Yes No Potential Reportable Occurrence? Yes No LCO Action Statement Entered? Yes No Corrective Action Taken: Reviewed By: Shift Manager Date Time Division Surveillance Coordinator Review: Approved By: Division Surveillance Coordinator Date Time Diesel Generator System Engineer Review: Reviewed By: Diesel Generator System Engineer Date Time M&TE Used:

Description STPEGS No. Cal. Due Date Recorder (Graphtec Model SR 7700, Yokogawa SL1400, or equivalent) Voltage Source (0-5 VDC) (Recorder Calibration) Voltage/Frequency Transducer Interface Stopwatch Digital Multi Meter (DMM) (Recorder Calibration) Fluke 187 Digital Multi Meter (DMM) or equivalent (Start Relay Verification)

Performers and Verifiers:

Name (Print) Signature Initials





Performers and Verifiers (continued): Name (Print) Signature Initials

Remarks:




1.0 Purpose and Scope

1.1 This procedure satisfies the requirements of the following Technical Specifications:

• 4.3.2.1.1.a.4 SI Manual Initiation Trip Actuating Device Operational Test (TADOT). (K825 and K828 Slave Relays only)

• 4.3.2.1.1.c.7 Actuation Train A Slave Relay output continuity and operability per the requirements of Technical Specification 4.3.2.1.1.c.7 (SI). (Partial)

• 4.3.2.2.2.a.9 Containment Pressure High-1 SI start of Standby DG ESF Response Time Test. (Partial)

• 4.3.2.2.3.a.9 PRZR Pressure-Low SI start of Standby DG ESF Response Time Test. (Partial)

• 4.3.2.2.5.a.9 Compensated Steam Line Pressure-Low SI start of Standby DG ESF Response Time Test. (Partial)

1.2 This procedure satisfies the requirements of the following Technical Specifications for DG 11(21):

• 4.8.1.1.2.a.1 Verifying greater than or equal to 60,500 gallons in the associated DGFOST.

• 4.8.1.1.2.a.2 Verifying the diesel starts from standby condition and accelerates to 600 rpm (nominal) in less than or equal to 10 seconds. The generator voltage and frequency SHALL be 4160 ± 416 volts (3744 to 4576) and 60 ± 1.2 Hz (58.8 to 61.2) within 10 seconds after the start signal.

• 4.8.1.1.2.a.3 Verifying the generator is synchronized, loaded to 5000 to 5500 KW, and operates with a load of 5000 to 5500 KW for at least 60 minutes.

• 4.8.1.1.2.a.4 Verifying the standby DG is aligned to provide standby power to the associated emergency busses.

• 4.8.1.1.2.b At least once per 31 days and after each operation of the diesel where the period of operation was greater than or equal to one (1) hour by checking for, and removing accumulated water from the associated DGFOST.




• 4.8.1.1.2.e.3 Verifying the generator capability to reject a load of 5500 KW without tripping. The generator voltage SHALL NOT exceed 5262 volts during and following the load rejection. This surveillance SHALL NOT be performed when in Modes 1 or 2.

• 4.8.1.1.2.e.5 Verifying that on a simulated SI signal, without LOOP, the DG starts on the auto-start signal and operates on standby for greater than or equal to 5 minutes. The generator voltage and frequency SHALL be 4160 ± 416 volts (3744 to 4576) and 60 ± 1.2 Hz (58.8 to 61.2) within 10 seconds after the auto-start signal. The steady-state generator voltage and frequency SHALL be maintained within these limits during this test. This surveillance SHALL NOT be performed when in Modes 1 or 2.

• 4.8.1.1.2.e.7 Verifying the standby DG operates for at least 24 hours. During the first 2 hours of this test, the DG SHALL be loaded to 5700 to 6050 KW, and during the remaining 22 hours of this test, the DG SHALL be loaded to 5000 to 5500 KW. The steady-state generator voltage and frequency SHALL be 4160 ± 416 volts (3744 to 4576) and 60 ± 1.2 Hz (58.8 to 61.2) during this test. Within 5 minutes after completing this 24-hour test, a fast start SHALL be performed per Technical Specification 4.8.1.1.2.a.2.

• 4.8.1.1.2.e.10 Verifying that with the standby DG operating in a test mode connected to its bus, a simulated SI signal overrides the test mode by: (1) Returning the DG to standby operation, and (2) Automatically energizing the ESF loads with offsite power. This surveillance SHALL NOT be performed when in Modes 1, 2, 3, or 4.

• 4.8.1.2 The surveillance requirements of Technical Specification 4.8.1.1.2.a.1, 4.8.1.1.2.a.2, 4.8.1.1.2.a.4, 4.8.1.1.2.b, 4.8.1.1.2.e.3, 4.8.1.1.2.e.5, 4.8.1.1.2.e.7, and 4.8.1.1.2.e.10 are satisfied for Modes 5 and 6. (Partial)

1.3 WHEN Section 5.3 (DG Auto Start on ESF Actuation) AND Section 5.14 (Restoration and Documentation) AND either Section 5.5 (DG One Hour Load Test) or Section 5.7 (DG Twenty-Four Hour Load Test) of this procedure have been successfully completed, THEN all the surveillance testing requirements of 0PSP03-DG-0001 [Standby Diesel 11(21) Operability Test], including the Slave Relay Test, will be satisfied.




2.0 Responsibilities

2.1 The Test Coordinator SHALL ensure the procedure revision is correct and all applicable Field Changes are incorporated.

2.2 The Shift Manager SHALL grant permission to perform this test.

2.3 This procedure SHALL be performed by Plant Operations.

2.4 I&C Maintenance will be required to perform the following:

2.4.1 Perform voltage checks.

2.4.2 Support the operation, installation and removal of the recorder, as applicable. (Reference Step 3.12)

2.5 WHEN "_____" (blank) follows a step, THEN the performer shall enter initials to verify step completion. Check Marks may be used where indicated in tables. If a conditional step is NOT required, enter N/A. Steps which are only applicable to the other Unit may be marked N/A.

NOTE

After completion, procedure routing is per 0PGP03-ZE-0004 (Plant Surveillance Program).

2.6 The following personnel SHALL review the test results:

• Test Coordinator

• Shift Manager

• Division Surveillance Coordinator

• Diesel Generator System Engineer




3.0 Precautions and Notes

3.1 IF this procedure can NOT be performed as written, THEN the procedure performer SHALL stop the test and immediately notify the Shift Manager.

3.2 IF this test is terminated for any reason, THEN immediately notify the Shift Manager.

3.3 IF any Acceptance Criteria are NOT met, THEN immediately notify the Shift Manager and document the failure per 0PGP03-ZE-0004 (Plant Surveillance Program)

3.4 This procedure should be reviewed in its entirety prior to performing the test and Sections of the procedure which are NOT to be performed should be marked N/A.

3.5 IF in Modes 1, 2, 3 or 4, THEN Section 5.4 (DG Test Mode Override) SHALL NOT be performed. (Technical Specification 4.8.1.1.2.e.10)

3.6 IF in Modes 1 or 2, THEN Section 5.6 (DG 5500 KW Load Reject) SHALL NOT be performed. (Technical Specification 4.8.1.1.2.e.3)

3.7 Acceptance Criteria steps are annotated with the letters AC in the left margin preceding the step.

3.8 Annunciators and ESF Status Monitoring Lampbox alarms associated with the performance of this test may be acknowledged and reset, as necessary, during procedure performance.

3.9 Operation of DG 11(21) SHALL be per 0POP02-DG-0001 [Emergency Diesel Generator 11(21)].

3.10 During operation of DG 11(21), (Operations Logs - Diesel Generator) 0OOI01-OL-0005 SHALL be maintained.

3.11 All DG starts SHALL be recorded and classified per the requirements of 0PSP03-ZQ-0025 (Diesel Generator Starting Classification). (SPR 890723)

3.12 Various diesel generator procedures provide guidance for installation and removal of the recorder to be utilized for monitoring DG voltage, frequency, speed and start time. Based on the scheduled testing sequence of 11(21) DG, installation of the recorder specified within this procedure may have been previously performed. When this occurs, pre-test calibration of the recorder per the guidelines provided in Addendum 1, DG 11(21) Recorder Installation/Removal is only required during initial installation of the recorder. Additionally, post-test calibration of the recorder is only required to be performed one time following completion of the last scheduled surveillance activity.




3.13 Technical Specification Surveillance Requirement 4.8.1.1.2.a.2 specifies the following:

• “Verifying the diesel starts from standby condition and accelerates to 600 rpm (nominal) in less than or equal to 10 seconds. The generator voltage and frequency SHALL be 4160 ± 416 volts (3744 to 4576) and 60 ± 1.2 Hz (58.8 to 61.2) within 10 seconds after the start signal.”

• The requirement to verify the diesel “accelerates to 600 rpm (nominal) in less than or equal to 10 seconds” is satisfied by verifying the DG frequency is 58.8 to 61.2 Hz within 10 seconds of the diesel start signal. DG frequency is directly related to DG rpm (i.e., 60 Hz is directly proportional to 600 rpm).

3.14 For the purpose of determining DG 11(21) Operability, the DG start time recorded at ZLP102 utilizing a recorder should take precedence over the DG start time recorded at CP003 utilizing a stopwatch. The recorder SHALL be used for diesel starts.

3.15 DG 11(21) should NOT be paralleled with the Emergency Bus 1L(2L) for the purpose of full load testing; however, the DG may be paralleled to the Emergency Bus 1L(2L) for a short period in order to support transfer of ESF Bus loads between the normal supply [13.8 KV STBY Bus 1F(2F)] and emergency supply [Emergency Bus 1L(2L)]. (Reference CREE 96-6171)

3.16 WHEN the DG is being paralleled OR operated in parallel with offsite power, THEN the following loads SHALL NOT be started or operated: (SPR 941728)

• “HHSI PUMP 1A(2A)” • “LHSI PUMP 1A(2A)” • “RHR PUMP 1A(2A)” • “CSS PUMP 1A(2A)” • “RCFC FAN 11A(21A)” • “RCFC FAN 12A(22A)”

3.17 DG full load fuel oil consumption is approximately 360 gph. IF DG 11(21) is to be maintained operable during the performance of this test, THEN the AFOST SHALL be available to maintain DGFOST 11(21) level greater than or equal to 60,500 gallons. (Technical Specification 4.8.1.1.2.a.1)

3.18 Hand held radios SHALL NOT be used in the vicinity of the Diesel Generator Control Cabinets. (Reference 7.4.21)

3.19 The DGFOST wide range level indication (CP003 panel meters, local control panel meters, and Plant Computer indication) will vary with fuel oil density and temperature changes.

3.20 The DGFOST narrow range level magnetic sightglass indicated levels lag behind actual level by approximately 1 hour.

0PSP03-DG-0016 Rev. 38 Page 10 of 99



3.21 The Control Room indicators should be monitored for level changes of desired quantities. (Plant Computer OR CP003)

3.22 Sections 5.3 through 5.13 of this surveillance procedure are written to stand alone with regard to performance of the Standby Diesel Twenty-Four Hour Load Test. DG Operating Procedure 0POP02-DG-0001 [Emergency Diesel Generator 11(21)] SHALL be referred to for lineups and additional procedural guidance NOT defined by, or contained within this surveillance procedure.

3.23 The “EMER STOP” plunger located on CP003 only functions when the DG “LOCAL/REMOTE TRANSFER SW” located on ZLP102 is selected to the “REMOTE” position.

3.24 WHEN the DG is operating in the Emergency Mode, THEN only the following conditions will trip the DG:

• Engine Overspeed • Generator Differential • Turbo Lube Oil/Engine Lube Oil Emergency Trip Coincidence. Two low pressure

trip circuits, each consisting of a turbo lube oil and engine lube oil pressure pair, exist. WHEN at least one low pressure is sensed on both trip circuits, THEN the DG will trip.

• BOTH “EMERGENCY STOP CIRCUIT 1” and “EMERGENCY STOP CIRCUIT 2” STOP push buttons depressed. (ZLP102)

• “EMER STOP” plunger pulled out. (CP003) (Reference Step 3.23)

3.25 Throughout the procedure, the term “recorder” is used for the strip chart, visicorder, scopecorder, or other equivalent recording device used to capture and display DG output voltage, frequency, speed, and startup parameters for verification of DG operation within the required Technical Specification acceptance criteria (i.e., Graphtec Model WR 7700, Yokogawa SL1400, or other equivalent recorder).

3.26 DG 11(21) should NOT be paralleled with the electrical grid if the requirements of 0POP04-ZO-0002, Natural or Destructive Phenomena Guidelines, have been implemented or will be required within the projected DG operating duration. (Reference 7.8.9)

3.27 (MODES 1-4 ONLY) This surveillance is written assuming 4.16 KV Bus E1A(E2A) is aligned to the Unit Auxiliary Transformer with the UAT Load Tap Changer “MODE SELECT (MODE SEL)” switch in “AUTO” (i.e., Normal Lineup). IF a bus alignment other than described above exists (i.e., Alternate Lineup), THEN 0POP02-AE-0002, Transformer Normal Breaker and Switch Lineup, SHALL be referred to for additional clarification and guidance regarding operation of the standby diesel while in the Alternate Lineup configuration.

0PSP03-DG-0016 Rev. 38 Page 11 of 99



3.28 WHEN the DG is operating in the Non-Emergency Mode, THEN any of the following conditions will trip the DG:

• High Temp Main, Connecting Rod or Generator Bearing • Excessive Vibration Engine or Generator Bearing • Failure Turbo Thrust Bearing • Jacket Water High Temperature • Engine Overspeed • Fail to Start • Generator Differential • Over current • Generator Reverse Power • Loss of Field • Under frequency • Exciter Shutdown • Generator Negative Sequence • Generator Ground • Turbo Lube Oil/Engine Lube Oil Trip. Two low pressure trip circuits, each

consisting of a turbo lube oil and engine lube oil pressure pair exist. WHEN any one low pressure is sensed in either trip circuit, THEN the DG will trip.

• “EMERGENCY STOP CIRCUIT 1” or “EMERGENCY STOP CIRCUIT 2” STOP push button depressed. (ZLP102)

• “EMER STOP” plunger pulled out. (CP003) (Reference Step 3.23)

3.29 IF it is necessary to immediately stop a DG, THEN any of the following methods may be utilized:

• The “EMERGENCY STOP CIRCUIT 1” and “EMERGENCY STOP CIRCUIT 2” STOP push buttons SHALL be depressed. (ZLP102)

• The “EMER STOP” plunger SHALL be placed in the “PULL TO STOP” position. (CP003) (Reference Step 3.23)

• IF both of the above identified methods fail to stop the DG, THEN at least one of the following methods SHALL be utilized to stop the DG:

• The fuel racks SHALL be manually closed by pulling down on the fuel rack lever until the DG shaft stops rotating. (Southwest Side of Engine Above Turning Gear)

• An overspeed trip SHALL be manually initiated at the Engine Overspeed Governor. (Top of Diesel on Generator End)

0PSP03-DG-0016 Rev. 38 Page 12 of 99



3.30 IF the load current from ESF Bus E1A(E2A) to either Standby Bus 1F(2F) or Emergency Bus 1L(2L) exceeds 1008 Amperes (excessive bus reverse power) during parallel operation, THEN the DG output breaker will trip open.

3.31 IF Class 1E DC control power is lost at any time the DG is operating, THEN the DG will shutdown.

3.32 IF Non-Class 1E DC control power is lost at any time while the DG is operating in the Emergency Mode, THEN the DG will shutdown when released from the Emergency Mode. The DG shutdown will occur even if the Non-Class 1E DC power has been restored.

3.33 IF the DG is operating in the Emergency Mode AND one of the following non-emergency mode engine trips (not test simulations) is received, THEN the DG will trip when released from the Emergency Mode: (ZLP102)

• “HIGH TEMP MAIN & CONN. ROD OR GEN. BRG.”, Window A-3 • “EXCESSIVE VIBRATION ENG. & GEN. BRG.”, Window A-4 • “FAILURE TURBO THRUST BEARING”, Window A-5 • “JACKET WATER HIGH TEMPERATURE”, Window A-6

3.34 WHEN DG 11(21) is operating in the Emergency Mode AND a non-emergency trip signal is received, THEN the “RESET” push button in the Main Control Room SHALL be depressed prior to releasing from Emergency Mode. IF the “RESET” push button is NOT depressed prior to releasing from Emergency Mode, THEN the DG will trip.

3.35 Prior to releasing DG 11(21) from the Emergency Mode, the MASTER TRIP CIRCUIT amber “RESET” light should be verified to be illuminated. IF the DG is released from Emergency Mode AND the MASTER TRIP CIRCUIT amber “RESET” light is NOT illuminated, THEN the DG will trip.

3.36 The “RELEASE” push button SHALL be depressed prior to resetting the “EMER STOP” plunger. IF the “RELEASE” push button is NOT depressed prior to resetting the “EMER STOP” plunger AND a DG start signal is sealed in on 1ESL1 or 1ESL2, THEN the DG will start.

3.37 IF an abnormal shutdown has occurred, THEN DO NOT operate the DG until the cause of trip has been determined and corrective action taken.

3.38 IF the DG DOES NOT complete the cooldown cycle, THEN a Condition Report SHALL be submitted and the Diesel Engineer contacted to determine the effect on DG 11(21) Operability.

3.39 WHEN DG 11(21) is paralleled with offsite power, THEN starting a 13.8 KV load on the same 13.8 KV bus as the parallel diesel may result in the DG output breaker tripping open.

3.40 DG 11(21) load SHALL NOT exceed 6050 KW for greater than 2 hours.

0PSP03-DG-0016 Rev. 38 Page 13 of 99



3.41 Generator voltage limits are 3744 volts to 4576 volts. Nominal Generator voltage in automatic is 4160 volts.

3.42 The Lube Oil and Jacket Water temperature differential of 10°F during maintenance and test mode starts prevents cylinder liner stress cracking, scuffing, and piston/cylinder head warping. IF Lube Oil and Jacket Water ΔT is GREATER THAN 10°F, THEN a Condition Report SHALL be initiated to recalibrate associated temperature switches. IF Lube Oil and Jacket Water ΔT is GREATER THAN 25°F OR either system temperature is LESS THAN OR EQUAL TO 110°F, THEN a Condition Report SHALL be initiated AND Engineering contacted to evaluate the condition. (References 7.4.24 and 7.8.10)

3.43 IF any of the following conditions exists, THEN the DG SHALL be declared inoperable:

• Jacket Water temperature less than 100°F • Lube Oil temperature less than 100°F • Both DG Starting Air Receivers contain less than 175 psig • DGFOST level less than 60,500 gallons

(Technical Specification 3.8.1.1, 3.8.1.2, 3.8.1.3) • “ENGINE START MODE” switch is in “IDLE” AND DG speed less than 600 rpm • “DG OUTP BKR” in “PULL TO LOCK” • Electro-Mechanical Governor “SPEED DROOP” control NOT set at “0” position • Electro-Mechanical Governor Load Limiter NOT set at “MAX. FUEL” position

3.44 WHEN the DG is NOT running, THEN normal oil levels for the following governors are:

• DG 11(21) Electro-Mechanical Governor- > sightglass reference line

• DG 11(21) Overspeed Governor - > sightglass reference line

3.45 The addition of oil to an operating DG can be accomplished by removing two inch fill connection cap located on the north east side of the sump and adding the desired amount of oil. DG oil sump level will rise approximately one inch for each 35 to 40 gallons of oil added. (IEC 80-005)

3.46 WHEN the plant is in Modes 1 through 4 AND the DG 11(21) “EMER STOP” plunger is placed in the “PULL TO STOP” position, THEN DG 11(21) SHALL be declared inoperable. DG 11(21) may be considered functional if a Control Room Operator is stationed to perform specified actions to return DG 11(21) to its required safety condition in the event of an ESF actuation. (SPR 933560) (Reference 7.7.14)

3.47 WHEN the plant is in Modes 5, 6, or Defueled AND the DG 11(21) “EMER STOP” plunger is placed in the “PULL TO STOP” position, THEN the DG may be considered operable provided a Dedicated Operator is stationed at the DG 11(21) controls to start the DG, if required. (SPR 933560)

0PSP03-DG-0016 Rev. 38 Page 14 of 99



3.48 “STANDBY FUEL OIL PUMP” status DOES NOT affect DG operability. (Reference 7.8.1)

3.49 The Standby Lube Oil and Standby Jacket Water Pumps are NOT required for DG operability. (Reference 7.8.6)

3.50 The 701 Digital governor control allows for frequency control using the “GOV” control switch while the diesel is operating in the EMERGENCY mode.

3.51 The 701 Digital governor control circuit is still enabled when the diesel is secured. Operating the “GOV” control switch with the diesel secured will change the frequency setpoint.

3.52 WHEN the “ENGINE START MODE” switch is in the intermediate position between “IDLE” and “RATED” with the diesel running, THEN the diesel speed will start to ramp down at a rate of 10 rpm per sec. Switching the position of the “ENGINE START MODE” switch should be performed without hesitation. WHEN switching is complete, THEN the diesel will return to its original setpoint.

3.53 During the slave relay test section, placing the “S” series test switch in “PUSH TO TEST” position will cause (and restoring it to “NORMAL” will clear) the following:

3.53.1 Red test light “10-T1” at “PROTECTION SYSTEM SAFEGUARDS TEST TRAIN A, CABINET NO. 1” (ZRR003) will be LIT.

3.53.2 “PROTECTION SYSTEM SAFEGUARDS TEST TRAIN A, CABINET NO. 1” (ZRR003) will be in test.

3.53.3 “PROTECTION SYSTEM LOGIC TRAIN R, LOGIC CABINET” (SSPS) (ZRR001) will be in “URGENT ALARM”.

3.53.4 Associated Annunciators will alarm.

3.54 A “MASTER RELAY DEFEAT SWITCH” (MRDS) is located at each of the following logic trains:

• At “PROTECTION SYSTEM LOGIC TRAIN R, LOGIC CABINET, LOGIC TEST PANEL” (SSPS) (ZRR001)

• At “PROTECTION SYSTEM LOGIC TRAIN S, LOGIC CABINET, LOGIC TEST PANEL” (SSPS) (ZRR008)

3.55 The “MASTER RELAY DEFEAT SWITCH” (MRDS) for both logic trains shall be set to identical positions.

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4.0 Prerequisites

4.1 Ensure the procedure revision is correct and all applicable Field Changes are incorporated. _____

4.2 Record the current plant Mode:

Mode __________ _____

4.3 Record the AS FOUND positions for the following Train R and S “MASTER RELAY DEFEAT SWITCH” and SSPS Actuation Train “MODE SELECTOR” Switches in Step 5.14.6.

• Train R “MASTER RELAY DEFEAT SWITCH” (ZRR001) _____

• Train S “MASTER RELAY DEFEAT SWITCH” (ZRR008) _____

• SSPS Actuation Train A “MODE SELECTOR” Switch (ZRR002) _____

• SSPS Actuation Train B “MODE SELECTOR” Switch (ZRR004) _____

• SSPS Actuation Train C “MODE SELECTOR” Switch (ZRR006) _____

4.4 IF in Mode 1, 2, 3 or 4, THEN record N/A in Section 5.4, DG Test Mode Override. _____

4.5 IF in Mode 1 or 2, THEN record N/A in Section 5.6, DG 5500 KW Load Reject. _____

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4.6 IF Section 5.7, DG Twenty-Four Hour Load Test, will be performed during Modes 1 or 2, THEN the following Prerequisites apply, OTHERWISE record N/A for Steps 4.6.1 through 4.6.7: (CR 95-11326)

4.6.1 Ensure that both DGs 12(22) and 13(23) are operable. _____

4.6.2 ENSURE Train A 4.16 KV Bus E1A(E2A) is fed from the respective Auxiliary Transformer as follows: Refer to 0POP02-AE-0002 (Transformer Normal Breaker and Switch Lineup).

• Aux 1F(2F) From UAT _____

• Stby 1F(2F) From Aux 1F(2F) _____

4.6.3 Ensure that both Bus E1B(E2B) and Bus E1C(E2C) are aligned to a separate Auxiliary or Standby Transformer from that which Bus E1A(E2A) is aligned per 0POP02-AE-0002 (Transformer Normal Breaker and Switch Lineup). _____

4.6.4 Consult STP Coordinator to ensure that offsite power grid conditions are predicted to be stable for the period that DG 11(21) will be paralleled to offsite power. _____

4.6.5 Ensure that DG 12(22) and 13(23) are NOT planned to be paralleled to offsite power while DG 11(21) is paralleled to offsite power. _____

4.6.6 Ensure that there will be no planned maintenance on required components of ESF Train B or C or the AFW system while DG 11(21) is paralleled to offsite power. _____

4.6.7 Ensure that the Symptoms or Entry Conditions for 0POP04-ZO-0002 “Natural or Destructive Phenomena Guidelines” DO NOT exist. _____

4.7 DG 11(21) is aligned for Standby Operation per 0POP02-DG-0001 [Emergency Diesel Generator 11(21)]. _____

4.8 Notify Mechanical Maintenance approximately 2 hours prior to starting the DG, to allow for performance of scheduled Preventive Maintenance (PMs). _____

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4.9 IF Section 5.3, DG Auto Start on ESF Actuation is being performed, THEN ensure the following conditions exist:

4.9.1 IF in Modes 1, 2, 3 or 4, THEN perform the following:

4.9.1.1 At “NSSS SSPS ACTUATION TRAIN A 3Z101(2)ZRR002”, Verify the green “OPERATE” light is lit. _____

4.9.1.2 At “NSSS SSPS ACTUATION TRAIN B 3Z101(2)ZRR004”, Verify the green “OPERATE” light is lit. _____

4.9.1.3 At “NSSS SSPS ACTUATION TRAIN C 3Z101(2)ZRR006”, Verify the green “OPERATE” light is lit. _____

4.9.1.4 At “NSSS SSPS LOGIC TRAIN R 3Z101(2)ZRR001”, Perform the following:

• Verify green TEST, “TRAIN R” light is lit. _____

• Verify amber TEST, “TRAIN S” light is lit. _____

4.9.1.5 At “NSSS SSPS LOGIC TRAIN S 3Z101(2)ZRR008”, Perform the following:

• Verify amber TEST, “TRAIN R” light is lit. _____

• Verify green TEST, “TRAIN S” light is lit. _____

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NOTE

The following steps ensure that a Containment Ventilation Isolation (CVI) signal is NOT present. Previously, a Train C electrical outage de-energized one of the radiation monitors causing a CVI condition with no obvious Control Room indications that the signal existed. WHEN the “NSSS SSPS ACTUATION TRAIN A 3Z101(2)ZRR002” “MODE SELECTOR” switch was placed in “OPERATE”, THEN the existing CVI signal caused a Train A CVI actuation. This could also occur during a Train A electrical outage. (SPR 921000)

4.9.2 IF in Modes 5, 6 or Defueled, THEN perform the following:

4.9.2.1 IF the Shift Manager has authorized testing with a standing CVI signal in, THEN perform the following:

• Document Shift Manager approval on PPDS Remarks. _____

• N/A Step 4.9.2.2 and GO TO Step 4.9.2.3. _____

4.9.2.2 IF both of the following conditions are met,

• Train R “MASTER RELAY DEFEAT SWITCH” is in “NORMAL”, “RX TRIP”, or “DEFEAT/CVI AVAIL”. (ZRR001)

• Train S “MASTER RELAY DEFEAT SWITCH” is in “NORMAL”, “RX TRIP”, or “DEFEAT/CVI AVAIL”. (ZRR008)

THEN verify the following at Panel CP023 for "REACTOR CONT BLDG PURGE ISOLATION" Radiation Monitors "A1RA-RI-8012B" and "C1RA-RI-8013B":

• Both Radiation Monitors are operational. _____

• No testing or maintenance is being performed on either Radiation Monitor. _____

• Compare the 10 minute trend on “RADIATION MONITORING RM-11 CRT” or the current reading on “RADIATION MONITORING INSTRUMENT PANEL” (CP023) to the alarm setpoints and verify Radiation Monitors are NOT in High Alarm or near the High Alarm Setpoint. _____

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4.9.2.3 IF both of the following conditions are met,

• Train R “MASTER RELAY DEFEAT SWITCH” is in “NORMAL” or “RX TRIP”. (ZRR001)

• Train S “MASTER RELAY DEFEAT SWITCH” is in “NORMAL” or “RX TRIP”. (ZRR008)

THEN verify NO ESF Actuation Signal is present at CP005 and CP006 Bistable Status Monitoring Panels. _____

4.9.3 IF performing this test in Plant Operating Modes 5, 6 or Defueled, THEN at “NSSS SSPS ACTUATION TRAIN A 3Z101(2)ZRR002”, ensure the “MODE SELECTOR” switch is in “OPERATE” and the green “OPERATE” light is lit. _____

4.9.4 IF performing test in Plant Operating Modes 5, 6 or Defueled, THEN ensure one of the following conditions is met to avoid a reactor trip signal. N/A the conditions NOT used: (Reference SPR 930641)

• Jumpers installed on the SSPS Logic cabinet Universal Boards using 0PMP08-SP-0001 (RPS/ESF System Normalization). _____

OR • Both Master Relay Defeat Switches (MRDS) are

in “DEFEAT/CVI AVAIL” or “DEFEAT ALL”: • Train R “MASTER RELAY DEFEAT SWITCH” (ZRR001). _____ • Train S “MASTER RELAY DEFEAT SWITCH” (ZRR008). _____

OR • Both “MODE SELECTOR” switches for SSPS Actuation

Trains B and C are in “OPERATE”: • At “NSSS SSPS ACTUATION TRAIN B

3Z101(2)ZRR004”, ensure the "MODE SELECTOR" switch is in “OPERATE” and the green "OPERATE" light is lit. _____

• At “NSSS SSPS ACTUATION TRAIN C 3Z101(2)ZRR006”, ensure the "MODE SELECTOR" switch is in “OPERATE” and the green "OPERATE" light is lit. _____

4.10 IF DG 11(21) is to be maintained operable during the performance of this test, THEN ensure the AFOST is available to maintain the DGFOST 11(21) level greater than or equal to 60,500 gallons. (Technical Specification 4.8.1.1.2.a.1) _____

4.11 Obtain a calibrated stopwatch accurate to ± 1%, to monitor the time for the DG to reach rated speed, voltage and frequency AND Record the STPEGS ID Number and Calibration Due Date of the stopwatch on the Procedure Performance Data Sheet (PPDS). _____

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NOTE

• The power cord used to supply power to the recorder should be ungrounded. (SPR 933560)

• IF Section 5.6 (DG 5500 KW Load Reject) will be performed, THEN the recorder SHALL be used.

• IF performing subsequent 0PSP03-DG-0013, Standby Diesel 11(21) LOOP-ESF Actuation Test, THEN test equipment may be installed per 0PSP03-DG-0013, Standby Diesel 11(21) LOOP-ESF Actuation Test.

4.12 IF test equipment installed per 0PSP03-DG-0013, Standby Diesel 11(21)

LOOP-ESF Actuation Test, THEN N/A Steps 4.13 and 5.1.4. _____

4.13 Ensure the following test equipment is obtained AND record the STPEGS ID Number and Calibration Due Date of the test equipment on the PPDS.

4.13.1 One (1) recorder equipped with the following voltage modules: (Graphtec Model SR 7700,Yokogawa SL1400, or equivalent) _____

4.13.1.1 Voltage Channel: Range 0 - 5 VDC, accuracy + 1.5% of full scale, or better.

4.13.1.2 Frequency Channel: Range 0 - 5 VDC, accuracy + 1.5% of full scale, or better.

4.13.1.3 Start Channel: Range 0 - 100 VDC, accuracy N/A - used for 125 VDC circuit energized indication.

4.13.1.4 Speed Channel: Range 0 - 5 VDC, accuracy + 1.5% of full scale, or better.

4.13.2 One (1) Frequency/Voltage Transducer Interface, accuracy + 0.1% of frequency at 60 Hz and + 0.1% of voltage at 4160 V. _____

4.13.3 One (1) DMM, range 0 - 5 VDC, accuracy + 0.35% of full scale, or better. _____

4.13.4 One (1) Voltage Source (0 - 5 VDC), accuracy N/A. _____

4.13.5 All required test leads. _____

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4.14 Obtain a Fluke 187 DMM or equivalent for verification of DG start relay contact closure (1ESL1 and 1ESL2) AND record the STPEGS ID Number and Calibration Due Date on the PPDS. _____

4.15 Record the following or N/A, as applicable, on the PPDS:

• Unit Number • Work Activity Number • Surveillance Test (ST) Number • Reason for Test _____

4.16 Evaluate current plant conditions, and note in the Remarks Section of the PPDS any changes in Work Activity Risk Assessment due to special plant conditions. _____

Work Activity Risk Assessment by Plant Mode Reactor Trip Potential:

Mode 1 Mode 2 Mode 3 Mode 4 Mode 5 Mode 6 Defueled LOW LOW NONE NONE NONE NONE NONE

Turbine Trip Potential:

Mode 1 Mode 2 Mode 3 Mode 4 Mode 5 Mode 6 Defueled LOW NONE NONE NONE NONE NONE NONE

ESF Actuation Potential:

Mode 1 Mode 2 Mode 3 Mode 4 Mode 5 Mode 6 Defueled LOW LOW LOW LOW LOW LOW LOW

4.17 Notify the Shift Manager to review Technical Specification 3.3.2, 3.8.1.1,

3.8.1.2, and 3.8.1.3 Operability and LCO requirements, as applicable. _____

4.18 Obtain the Shift Manager’s signature on the PPDS, for administrative approval to perform test. _____

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5.0 Procedure

5.1 Preparation

5.1.1 Ensure the Prerequisites Section has been completed and Precautions and Notes Section has been read by the Test Coordinator. _____

5.1.2 Conduct a pre-job briefing, including any changes in Work Activity Risk Assessment as noted in the Remarks Section of the PPDS. _____

5.1.3 Ensure a Control Room Logbook entry documents the commencement of this surveillance test. _____

5.1.4 IF a recorder was NOT previously installed at DG 11(21), THEN perform the following to install the recorder:

5.1.4.1 Request I&C Maintenance perform a pre-test calibration of the recorder per the guidelines provided in Addendum 1 (DG 11(21) Recorder Installation/Removal). (NOT required for Yokagawa recorder.) _____

NOTE

• WHEN the plant is in Modes 1 through 4 AND the DG 11(21) “EMER STOP” plunger is placed in the “PULL TO STOP” position, THEN DG 11(21) SHALL be declared inoperable. DG11(21) may be considered functional if a Control Room Operator is stationed to ensure Step 5.1.4.6 is performed to return DG 11(21) to its required safety condition in the event of an ESF actuation. (SPR 933560) (Reference 7.7.14)

• WHEN the plant is in Modes 5, 6 or Defueled AND the DG 11(21) “EMER STOP” plunger is placed in the “PULL TO STOP” position, THEN the DG may be considered operable provided a Dedicated Operator is stationed at the DG 11(21) controls to start the DG, if required. (SPR 933560)

5.1.4.2 Ensure the DG 11(21) “EMER STOP” plunger placed

in the “PULL TO STOP” position. (CP003) (SPR 933560) _____

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NOTE


• WHEN the recorder is being connected to the DG, THEN the recorder should be unplugged. (SPR 933560)

5.1.4.3 Request I&C Maintenance to perform the following:

• Install the recorder and voltage/frequency transducer interface at DG 11(21) per Addendum 1, DG 11(21) Recorder Installation/Removal. (References 7.4.4 and 7.4.22) _____ I&C Maintenance

_____ I&C Maintenance Dual Verif _____ Maintenance Supervisor Ind. Verif

• Ensure a 250 OHM test resistance is installed across the 65GSC 701 Digital Speed Control output as shown on Addendum 1, DG 11(21) Recorder Installation/Removal. _____

I&C Maintenance _____ I&C Maintenance Dual Verif _____ Maintenance Supervisor Ind. Verif

• IF a Graphtec Recorder is being utilized, THEN perform the following:

1. Ensure ALL Channel Module “VERNI” switches are selected to “OFF”. _____

I&C Maintenance _____ Maintenance Supervisor Ind. Verif

2. Ensure a Chart Recorder Printout indicates “FIX” in the “Verni.” column for ALL Channel Modules. _____

I&C Maintenance

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5.1.4.4 Momentarily depress the DG 11(21) “RELEASE” pushbutton. (CP003) _____

5.1.4.5 Verify the “EMERGENCY MODE” white light is extinguished to ensure the 1ESL1 and 1ESL2 Emergency Start Latch Relays reset. (ZLP102) _____

5.1.4.6 Place the DG 11(21) “EMER STOP” plunger in the “PUSH TO RESET” position. (CP003) _____

Perform

_____ Ind. Verif

NOTE

Train B and Train C equipment may be operated, as necessary, to support plant operations. (SPR 941728)

5.1.5 Ensure the following Train A equipment is NOT in operation: (SPR 941728)

• “HHSI PUMP 1A(2A)” _____

• “LHSI PUMP 1A(2A)” _____

• “RHR PUMP 1A(2A)” _____

• “CSS PUMP 1A(2A)” _____

• “RCFC FAN 11A(21A)” _____

• “RCFC FAN 12A(22A)” _____

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5.2 DG Prestart Inspection

5.2.1 Ensure the ECW System is providing at least 1486 gpm cooling flow to DG 11(21) as demonstrated on at least one of the following indications:

• “1(2)-EW-FI-6855 DIESEL GENERATOR #11(21) ECW RETURN FLOW INDICATOR” (DGB, NW Corner) _____

• Plant Computer /QDPS _____

5.2.2 Verify the following:

PARAMETER INSTR READING RANGE

Turbo Lube Oil Pressure PI-5498 (ZLP102) 4 – 13 psig

Engine Lube Oil Pressure PI-5497 (ZLP102) 5 – 15 psig

Jacket Water Stand Pipe Level LG-5400 (NW Skid) Between 3 and 4

inches Below Normal

Engine Sump Oil Level LG-5496 (NE Skid) 0 (Blue Line)

± 2 inches

Electro-Mechanical Governor Oil Level

Sightglass (SW Skid)

≥ Sightglass Reference Line when

DG is S/D

Overspeed Governor Oil Level Sightglass (SE Skid)


DG is S/D

Any Visible Leaks Evaluated (Water, Fuel Oil, Lube Oil, Air) N/A Leaks Evaluated

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NOTE

• WHEN the Diesel Generator is NOT running AND jacket water temperature is approximately 175°F, THEN level should be +1 to +7 inches ABOVE the NORMAL mark.

• WHEN the Diesel Generator is NOT running AND jacket water temperature is approximately 120-130°F, THEN level should be adjusted between 3 and 4 inches BELOW the NORMAL mark. (References 7.8.11 and 7.8.12)

5.2.3 ENSURE jacket water standpipe level adjusted for the applicable

operating condition as follows: (Reference 7.4.23)

5.2.3.1 IF jacket water standpipe level is low, THEN PERFORM the following:

a. OPEN "1(2)-JW-0091 J.W. M/U ISOL VALVE". (W of Jacket Water Standpipe) _____

b. WHEN the desired jacket water standpipe level is obtained, THEN CLOSE "1(2)-JW-0091 J.W. M/U ISOL VALVE" _____ Perform

_____ Ind. Verif

5.2.3.2 IF jacket water standpipe level is high, THEN PERFORM the following:

a. OPEN "1(2)-JW-0005 J.W. STANDPIPE DRN VALVE". (SW of JW Cooler Under Grate) _____

b. WHEN the desired jacket water standpipe level is obtained, THEN CLOSE "1(2)-JW-0005 J.W. STANDPIPE DRN VALVE". _____ Perform

_____ Ind. Verif

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5.2.4 IF Jacket Water Stand Pipe Level additions were performed, THEN RECORD on 0OOI01-OL-0005, Operations Logs - Diesel Generator. _____

5.2.5 RECORD DGFOST 11(21) level from one of the following: _____

• LI-9109 (CP003) __________gal

• Plant Computer Point DOLA9109 __________gal

• “1(2)-LI-9109B DIESEL FUEL OIL STORAGE TANK #11(21) LEVEL INDICATOR” (55' DGB Outside of S. Tank Room Door) __________gal

5.2.5.1 IF the DGFOST magnetic sightglass is desired to be used to obtain FOST level, THEN perform the following:

a. Ensure at least 1 hour has elapsed following either diesel run or fuel oil storage tank fill. _____

b. Record “1(2)-DO-LI-9110B DIESEL GENERATOR #11(21) FUEL OIL STORAGE TANK LEVEL INDICATOR” (Magnetic Sightglass, 55 ft DGB Exhaust Silencer Area) _____

__________gal

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NOTE

IF any of the following conditions are met, THEN additional pre-lubing of DG 11(21) is NOT required:

• The DG was run in the last 8 hours.

• The DG standby lube oil pump was run in the last 8 hours.

5.2.6 IF additional pre-lubing of the DG is required, THEN perform the following: (ZLP102)

5.2.6.1 Place the Lube Oil “HEATER” control switch in the “OFF” position. _____

5.2.6.2 Place the Standby “LUBE OIL PUMP” control switch in the “HAND” position. (SPR 910034) _____

5.2.6.3 WHEN approximately 1 minute has elapsed from the performance of Step 5.2.6.2, THEN return the Standby “LUBE OIL PUMP” control switch to the “AUTO” position. _____

5.2.6.4 Place the Lube Oil “HEATER” control switch in the “AUTO” position. _____

5.2.7 Verify Annunciator Lampbox 3M03, Window A-4 “DG 11(21) TRBL” annunciator clear. (CP003) _____

5.2.8 Ensure the significance of any illuminated annunciators on Annunciator Lampbox 102, has been evaluated. (ZLP102) _____

5.2.9 GO TO the next appropriate procedure section depending on the reason for performing this procedure. _____

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NOTE

IF Section 5.3 is being performed in Modes 1 or 2, THEN credit for surveillance 4.8.1.1.2.e.5 SHALL NOT be taken.

5.3 DG Auto Start on ESF Actuation

5.3.1 Establish communications between the Main Control Room and the following locations:

• DG 11(21) _____

• NSSS Cabinets ZRR002-1 and ZRR003-2 _____

CAUTION

I&C Maintenance SHALL NOT be allowed to connect any test equipment utilized in Step 5.3.12 prior to the performance of Step 5.3.12. IF the Fluke 187 DMM or equivalent is connected prior to the performance of Step 5.3.12, THEN DG 11(21) may receive a premature start signal. (SPR 900177)

NOTE

• The terminal blocks referred to in Steps 5.3.2 and 5.3.12 are located at “NSSS SSPS ACTUATION TRAIN A 3Z101(2)ZRR002”, “OUTPUT CABINET NO. 1”. This cabinet will be referred to as ZRR002-1 during the performance of the respective steps.

• Step 5.3.12 verifies control relays 1ESL1 and 1ESL2 seal-in by verifying a Voltage drop of less than 10 VDC across the terminals.

5.3.2 At ZRR002-1, Notify I&C Maintenance to locate the following

contact terminals in preparation for performance of Step 5.3.12:

• Slave Relay K825 contacts 11-12 Terminal Board 820 terminals 5 (+) and 6 (-). _____

• Slave Relay K825 contacts 13-14 Terminal Board 820 terminals 7 (+) and 8 (-). _____

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NOTE

The recorder speed may be reduced to 10 mm/sec approximately 20 seconds following start of the DG.

5.3.3 At ZLP102, WHEN directed by Control Room personnel, THEN

perform the following:

• Ensure the recorder is started at 100 mm/sec. _____

• WHEN approximately 20 seconds have elapsed since the DG was started, THEN reduce the recorder speed to 10 mm/sec. _____

CAUTION

The “SAFETY INJECTION” switch “S214” SHALL NOT be depressed during performance of Step 5.3.4 until directed by Control Room personnel. WHEN “SAFETY INJECTION” switch “S214” is depressed, THEN DG 11(21) will start.

NOTE

• The test switches and indications referred to in Steps 5.3.4, 5.3.7 and 5.3.8 are located at “NSSS SAFEGUARD TST CAB TRAIN A 3Z101(2)ZRR003”, “CABINET NO. 2”. This cabinet will be referred to as ZRR003-2 during the performance of the respective steps.

• Steps 5.3.4 and 5.3.5 SHALL be performed concurrently.

• DG 11(21) will be started and Slave Relay K825 latched during performance of Step 5.3.4.

5.3.4 At ZRR003-2, WHEN directed by Control Room personnel, THEN turn “SAFETY INJECTION” switch “S214” to the “PUSH TO TEST” position, HOLD the switch there, and wait for a countdown from Control Room personnel. DO NOT DEPRESS switch “S214” until directed by Control Room personnel. WHEN directed by Control Room personnel, THEN momentarily depress “SAFETY INJECTION” switch “S214”, then release and return to “NORMAL”. _____ Perform

_____ Dual Verif

DV

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NOTE

Illumination of the blue READY FOR LD light SHALL NOT be utilized as an indication of DG speed, voltage and frequency. The blue READY FOR LD light provides indication that DG speed is ≥ 540 rpm (54 Hz) and generator voltage is ≥ 3955 V. (CP003)

5.3.5 At CP003, Monitor the time for the DG to reach rated speed, voltage

and frequency by performing the following:

5.3.5.1 WHEN the diesel start signal is initiated, THEN start the stopwatch. _____

5.3.5.2 WHEN the following DG operating parameters are established, THEN stop the stopwatch: _____

• Voltage - 4160 ± 416 V (3744 - 4576 V)

• Frequency - 60 ± 1.2 Hz (58.8 - 61.2 Hz)

5.3.5.3 Record the time for DG voltage to be within 3744 V and 4576 V, and frequency to be within 58.8 Hz and 61.2 Hz

__________ seconds _____

Acceptance Criteria: < 10 seconds

5.3.5.4 Record DG 11(21) steady state voltage:

__________ V _____

Acceptance Criteria: 4160 ± 416 V (3744 - 4576 V)

5.3.5.5 Record DG 11(21) steady-state frequency:

__________ Hz _____

Acceptance Criteria: 60 ± 1.2 Hz (58.8 - 61.2 Hz)

5.3.6 At CP003, Verify DG 11(21) “DG OUTP BKR” open. _____

5.3.7 Record the time and date DG 11(21) was started:

Time __________ Date __________ _____

AC

AC

AC

AC

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5.3.8 At ZRR003-2, WHEN directed by Control Room personnel, THEN turn “RESET” switch “S221” to “RESET” and return to “NORMAL”. _____

Perform _____ Dual Verif

5.3.9 At ZRR003-2, Verify red test light “11-T1” is extinguished. _____

5.3.10 At CP022, Verify DG 11(21) “EMER FAN 11A(21A)” started. _____

5.3.11 At CP022, Verify DG 11(21) “NORMAL FAN 11A(21A)” stopped. _____

5.3.12 At ZRR002-1, WHEN directed by Control Room personnel, THEN verify the following utilizing a Fluke 187 DMM or equivalent in the DC voltage mode:

5.3.12.1 Voltage drop across Terminal Board 820, terminals 5 (+) and 6 (-) is less than 10 VDC (verifies control relay 1ESL1 seal-in). _____

5.3.12.2 Voltage drop across Terminal Board 820, terminals 7 (+) and 8 (-) is less than 10 VDC (verifies control relay 1ESL2 seal-in). _____

NOTE

• IF in Mode 3, 4, 5, 6 or Defueled, THEN the recorder SHALL NOT be stopped until at least 5 minutes have elapsed since the performance of Step 5.3.7 to ensure the 5 minute operation requirement of Technical Specification 4.8.1.1.2.e.5 is satisfied.

• Restoration and Documentation Step 5.14.9 may be performed at any time following completion of Step 5.3.13 or 5.3.14, as applicable.

5.3.13 IF in Mode 3, 4, 5, 6 or Defueled, THEN perform the following:

5.3.13.1 WHEN at least 5 minutes have elapsed from the time recorded in Step 5.3.7, THEN record the time and date:

Time __________ Date __________ _____

5.3.13.2 Notify personnel stationed locally at DG 11(21) to stop the recorder. _____

AC

AC

DV

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5.3.14 IF in Mode 1 or 2, THEN notify personnel stationed locally at DG 11(21) to stop the recorder. _____

5.3.15 ENSURE the recorder trace is labeled with the procedure number, date of test, time of test, recorder operator name(s), recorder scaling, recorder speed, channel identification, and any additional pertinent information. _____

5.3.16 At CP003, Momentarily depress the DG 11(21) “RESET” push button to ensure the non-emergency trip logic reset. _____

NOTE

Prior to releasing DG 11(21) from Emergency Mode, the MASTER TRIP CIRCUIT “RESET” light should be verified to be illuminated. IF the DG is released from Emergency Mode AND the MASTER TRIP CIRCUIT “RESET” light is NOT illuminated, THEN the DG will trip.

5.3.17 At ZLP102, Verify the MASTER TRIP CIRCUIT “RESET” light

illuminated. _____

5.3.18 At CP003, WHEN desired, THEN release DG 11(21) from Emergency Mode by momentarily depressing the DG 11(21) “RELEASE” push button. _____

5.3.19 At ZLP102, Verify the “EMERGENCY MODE” white light is extinguished to ensure the 1ESL1 and 1ESL2 Emergency Start Latch Relays reset. (ZLP102) _____


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5.4 DG Test Mode Override

CAUTION

IF in Mode 1, 2, 3, or 4, THEN Section 5.4, DG Test Mode Override, SHALL NOT be performed. (Technical Specification 4.8.1.1.2.e.10)

5.4.1 Synchronize and Load DG 11(21) to approximately 100 to 200 KW

per Section 5.9, DG Loading. _____

NOTE

• The test switches and indications referred to in Steps 5.4.2, 5.4.9, and 5.4.10 are located at “NSSS SAFEGUARD TST CAB TRAIN A 3Z101(2)ZRR003”, “CABINET NO. 2”. This cabinet will be referred to as ZRR003-2 during the performance of the respective steps.

• Slave Relay K825 will be latched during performance of Step 5.4.2.

5.4.2 At ZRR003-2, WHEN directed by Control Room

personnel, THEN turn “SAFETY INJECTION” switch “S214” to the “PUSH TO TEST” position and momentarily depress, then release and return to “NORMAL”. _____


5.4.3 At ZLP102, Verify the “EMERGENCY MODE” white light on. _____

5.4.4 At CP003, Verify DG 11(21) “DG OUTP BKR” open. _____

5.4.5 At CP003, Verify 4.16 KV Bus E1A(E2A) is energized from offsite power. _____

5.4.6 At CP003, Verify DG 11(21) NOT tripped. _____

5.4.7 Record DG 11(21) steady-state voltage:

__________ V _____

Acceptance Criteria: 4160 ± 416 V (3744 - 4576 V)

AC

AC

AC

AC

AC

DV

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5.4.8 Record DG 11(21) steady-state frequency:

__________ Hz _____


5.4.9 At ZRR003-2, WHEN directed by Control Room personnel, THEN turn “RESET” switch “S221” to “RESET” and return to “NORMAL”. _____



5.4.11 Ensure the DG 11(21) “DG OUTP BKR” control switch in the auto after open position (green flagged). (CP003) _____

Perform _____

Ind. Verif

5.4.12 At CP003, Momentarily depress the DG 11(21) “RESET” push button to ensure the non-emergency trip logic reset. _____

NOTE

Prior to releasing DG 11(21) from the Emergency Mode, the MASTER TRIP CIRCUIT “RESET” light should be verified to be illuminated. IF the DG is released from Emergency Mode AND the MASTER TRIP CIRCUIT “RESET” light is NOT illuminated, THEN the DG will trip.


illuminated. _____




AC

DV

AC

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NOTE

• Section 5.5 provides guidance for a DG One Hour Load Test with load between 5100 KW and 5400 KW.

• Section 5.5 was incorporated as a convenient way to satisfy the DG One Hour Load Test requirement performed within 0PSP03-DG-0001 [Standby Diesel 11(21) Operability Test], without having to transition out of this procedure (i.e., for Operator convenience all required testing for DG Operability can be satisfied within this surveillance).

• As delineated within Step 1.3, “WHEN Section 5.3 (DG Auto Start on ESF Actuation) AND Section 5.14 (Restoration and Documentation) AND either Section 5.5 (DG One Hour Load Test) or Section 5.7 (DG Twenty-Four Hour Load Test) of this procedure have been successfully completed, THEN all the surveillance testing requirements of 0PSP03-DG-0001 [Standby Diesel 11(21) Operability Test], including the Slave Relay Test, will be satisfied”.

5.5 DG One Hour Load Test

5.5.1 At CP003, synchronize and load DG 11(21) to obtain the following DG loads per Section 5.9, DG Loading:

• Load between 5100 KW and 5400 KW (5250 KW nominal) _____

• Reactive Load between 0 and 500 KVAR (200 KVAR nominal) _____

5.5.2 Record the date and time DG 11(21) load was raised to between 5100 KW and 5400 KW (5250 KW nominal).

Date __________ Time __________ _____

5.5.3 Notify the local DG Operator to commence maintaining Logs per 0OOI01-OL-0005, Operations Logs - Diesel Generator. _____

5.5.4 Verify "DG 11(21) BKR CLOSED" light is illuminated. (ESF Sequencer, ZLP801 “INPUT STATUS INDICATOR”) _____

5.5.4.1 IF light is NOT illuminated in Step 5.5.4, THEN initiate a Condition Report. _____

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NOTE

Momentary transients outside of 5100 KW to 5400 KW due to changing conditions on the grid SHALL NOT invalidate the test.

5.5.5 Continue to operate DG 11(21) for at least 1 hour at a load of between 5100 KW and 5400 KW (5250 KW nominal) while performing the following:

5.5.5.1 Verify there are no excessive oil, fuel oil, water, or air leaks on the diesel engine or auxiliaries. _____

5.5.5.2 Verify all Annunciator Lampbox 102 alarms are extinguished, explained or corrective actions initiated to extinguish the annunciator. _____

5.5.5.3 Verify the generator brushes are NOT excessively sparking or chattering. _____

5.5.5.4 IF there are any equipment deficiencies, THEN record in the Remarks Section of the PPDS AND initiate Condition Reports to take corrective action. _____

5.5.6 WHEN DG 11(21) has operated at a load between 5100 KW and 5400 KW (5250 KW nominal) for at least 1 hour from the time recorded in Step 5.5.2, THEN record the date and time DG 11(21) load test completed.

Date __________ Time __________ _____

Acceptance Criteria: > 1 hour elapsed since time recorded in Step 5.5.2.


AC

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5.6 DG 5500 KW Load Reject

CAUTION

IF in Modes 1 or 2, THEN Section 5.6, DG 5500 KW Load Reject, SHALL NOT be performed. (Technical Specification 4.8.1.1.2.e.3)

NOTE

• Technical Specification 4.8.1.1.2.e.3 requires the DG to reject a load of 5500 KW without tripping. For conservatism, the DG should be loaded an additional 100 KW to ensure compliance with Technical Specification 4.8.1.1.2.e.3. (CR 94-2525)

• Generator Reactive Power (KVAR) should be maintained positive while performing Step 5.6.1.

5.6.1 At CP003, synchronize and load DG 11(21) to obtain the following

DG loads per Section 5.9, DG Loading:

• Load at 5600 KW (nominal) (CR 94-2525) _____

• Reactive Load between 0 and 500 KVAR (200 KVAR nominal) _____

5.6.2 Record DG 11(21) KW and KVAR load:

__________ KW _____

__________ KVAR _____

NOTE

The recorder may be stopped after recorder indications stabilize following performance of the load reject.

5.6.3 At ZLP102, WHEN directed by Control Room personnel, THEN

start the recorder at 100 mm/sec. _____

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NOTE

• Steps 5.6.4 through 5.6.10 test Slave Relay K828. Operation of Slave Relay K828 will trip the DG output breaker without placing the DG in Emergency Mode.

• The test switches and indications referred to in Steps 5.6.4, 5.6.9 and 5.6.10 are located at “NSSS SAFEGUARD TST CAB TRAIN A 3Z101(2)ZRR003”, “CABINET NO. 1”. This cabinet will be referred to as ZRR003-1 during the performance of the respective steps.

5.6.4 At ZRR003-1, WHEN directed by Control Room personnel,

THEN turn “SAFETY INJECTION” switch “S106” to “PUSH TO TEST” and momentarily depress, then release and return to “NORMAL”. _____


5.6.5 At CP003, Verify DG 11(21) “DG OUTP BKR” opened. _____

5.6.6 At CP003, Verify DG 11(21) NOT tripped. _____

NOTE

Restoration and Documentation Step 5.14.10 may be performed at any time following completion of Step 5.6.7.

5.6.7 At ZLP102, WHEN strip recorder indications stabilize following

performance of the load reject, THEN stop the recorder. _____

5.6.8 At ZLP102, Ensure the recorder trace is labeled with the procedure number, step number, date of test, time of test, recorder operator name(s), recorder scaling, recorder speed, channel identification, and any additional pertinent information. _____

5.6.9 At ZRR003-1, WHEN directed by Control Room personnel, THEN Turn “RESET” switch “S121” to “RESET” and return to “NORMAL”. _____


AC

AC

DV

DV

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Perform

_____ Ind. Verif

5.6.12 Adjust generator frequency to obtain 60 Hz (nominal) using the DG 11(21) “GOV” switch. _____

5.6.13 IF no further testing is required, THEN perform the following.

5.6.13.1 Ensure the “ENGINE START MODE” switch is in the “RATED” position. (ZLP102) _____ Perform

_____ Ind. Verif

5.6.13.2 Secure DG 11(21) per Section 5.11, DG Shutdown. _____

5.6.13.3 Perform Section 5.14, Restoration and Documentation. _____

AC

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CAUTION IF the UAT Load Tap Changer “MODE SELECT (MODE SEL)” switch is placed in “MANUAL” during performance of Step 5.7.2.3 AND Standby Diesel 11(21) trips during testing, THEN the UAT Load Tap Changer “MODE SELECT (MODE SEL)” switch SHALL be immediately placed in “AUTO” to allow bus voltage to be automatically controlled. (Reference 7.8.17)

NOTE

• Technical Specification 4.8.1.1.2.e.7 specifies that during the first 2 hours of the 24 hour load test, the generator SHALL be loaded to between 5700 and 6050 KW. For conservatism, the DG load should be maintained between 5800 and 5950 KW to ensure compliance with Technical Specification 4.8.1.1.2.e.7. (CR 94-2525)

• IF in Modes 5, 6, or Defueled, THEN the “MODE SELECTOR” switch at “NSSS SSPS ACTUATION TRAIN A 3Z101(2)ZRR002” is NOT required to be in “OPERATE” for performance of Section 5.7, DG Twenty-Four Hour Load Test.

• The following DG inspections should be performed during the DG Twenty-Four Hour Load Test: o Verify no excessive oil, fuel oil, water, or air leaks on the diesel engine or auxiliaries. o Verify all Annunciator Lampbox 102 alarms are extinguished, explained, or corrective

actions initiated to extinguish the annunciator. o Verify the generator brushes are NOT excessively sparking or chattering.

• Any equipment deficiencies SHALL be noted in the Remarks Section of the PPDS, and a Condition Report SHALL be initiated to take corrective action.

• The indicated voltage adjustment band of 4120 to 4309 V when operating the UAT Load Tap Changer “MODE SELECT (MODE SEL)” in “MANUAL” was established within CREE 11-17472-59. Maintaining a voltage band of 4120 to 4309 V on 4.16 KV Bus E1A(E2A) with the UAT LTC in “MANUAL” ensures the associated ESF buses are maintained within applicable voltage limitations.

• Changes to the UAT Load Tap Changer position should be made slowly. • Depending on plant conditions, lowering the voltage below 4000 VAC could cause the

ESF Diesel Generator to start and load on the ESF bus OR trip the 4.16 KV feeder breaker to the bus if the Degraded or Undervoltage setpoints are reached.

• (MODES 1-4 ONLY) Performance of Section 5.7 places the respective unit’s electrical bus alignment in an “Alternate Lineup” configuration due to realignment of 4.16 KV Bus E1C(E2C), and manual operation of the UAT LTC. 0POP02-AE-0002, Transformer Normal Breaker and Switch Lineup, SHALL be referred to for additional clarification and guidance regarding operation of the standby diesel while in the “Alternate Lineup” configuration.

5.7 DG Twenty-Four Hour Load Test

5.7.1 IF 13.8 KV Bus voltage is less than 13.3 KV, THEN contact System Engineer for evaluation. _____

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5.7.2 IF UAT is supplying Train A 4.16 KV Bus, THEN perform the following:

5.7.2.1 Ensure Bus E1C(E2C) is aligned to a separate Auxiliary or Standby Transformer from that which Bus E1A(E2A) is aligned per 0POP02-AE-0002 (Transformer Normal Breaker and Switch Lineup). _____

5.7.2.2 Ensure 13.8 KV Busses remain greater than or equal to 13.3 KV during UAT Tap Changing evolutions. _____

CAUTION IF in Modes 1-4, AND the UAT LTC is manually adjusted to a tap position of LESS THAN 10L (i.e. “9L”, “8L”, etc.), THEN Technical Specification LCO 3.8.1.1.a for the loss of one required offsite A.C. electrical power sources SHALL be entered. (Reference 7.8.18)

5.7.2.3 Ensure UAT Load Tap Changer “MODE SELECT

(MODE SEL)” is in “MANUAL”. _____

5.7.2.4 Manually adjust Auxiliary Bus voltage by using UAT Load Tap Changer “VOLT ADJUST (VOLTAGE ADJUST)” to “RAISE” or “LOWER” to ensure bus voltage is between 4120 V - 4309 V on Train A 4.16 KV Bus E1A(E2A). (Reference 7.8.18) _____

5.7.3 IF a Standby Transformer is supplying Train A 4.16 KV Bus, THEN perform the following:

5.7.3.1 Ensure 480 V LC bus voltage is LESS THAN 507 V. (EAB 10’ Swgr Rm) _____

5.7.3.2 IF 480 V LC bus voltage is GREATER THAN or EQUAL to 507 V, THEN perform the following: (Reference 7.8.14)

a. Suspend performance of Section 5.7. _____

b. Ensure the “ENGINE START MODE” switch in the “RATED” position. (ZLP102) _____ Perform

_____ Ind. Verif

c. GO TO Section 5.11, DG Shutdown. _____

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5.7.4 At CP003, synchronize and load DG 11(21) to obtain the following DG loads per Section 5.9, DG Loading:

• Load between 5800 KW and 5950 KW (CR 94-2525) _____

• Reactive Power between 3400 KVAR and 3800 KVAR _____

• IF UAT is supplying Train A 4.16 KV Bus, THEN manually adjust Auxiliary Bus voltage by using UAT Load Tap Changer “VOLT ADJUST (VOLTAGE ADJUST)” to “RAISE” or “LOWER” to ensure bus voltage is between 4120 V - 4309 V on Train A 4.16 KV Bus E1A(E2A). (CP010) _____

5.7.5 Notify the local DG Operator to commence maintaining Logs per 0OOI01-OL-0005 (Operations Logs - Diesel Generator). _____

5.7.6 Verify "DG 11(21) BKR CLOSED" light is illuminated. (ESF Sequencer, ZLP801 “INPUT STATUS INDICATOR”) _____

5.7.6.1 IF light is NOT illuminated in Step 5.7.6, THEN initiate a Condition Report. _____

5.7.7 During the 24 hour run, while the ESF Diesel is at stable 100% load, observe the ESF Diesel exhaust for visible emissions, AND check mark the results below. _____

Diesel Exhaust Emissions: VISIBLE _____ NOT VISIBLE _____

5.7.7.1 IF visible emissions are present, THEN contact Chemistry (Environmental) to quantify opacity (Smoke particulate content). (Reference 7.8.4) _____

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CAUTION

IF in Modes 1-4, AND the UAT LTC is manually adjusted to a tap position of LESS THAN 10L (i.e. “9L”, “8L”, etc.), THEN Technical Specification LCO 3.8.1.1.a for the loss of one required offsite A.C. electrical power sources SHALL be entered. (Reference 7.8.18)

NOTE

Momentary transients outside of 5800 KW to 5950 KW, and 3400 KVAR to 3800 KVAR due to changing conditions on the grid SHALL NOT invalidate the test. (Technical Specification 4.8.1.1.2.e.7)

5.7.8 Continue to operate DG 11(21) for at least 2 hours while maintaining (adjust as necessary) the following parameters:

• Load between 5800 KW and 5950 KW (5900 KW nominal), and

• Reactive Power between 3400 KVAR and 3800 KVAR, and

• IF UAT is supplying Train A 4.16 KV Bus, THEN 4.16 KV Bus E1A(E2A) voltage is between 4120 and 4309 V.

Record the required information on Table 1 DG 11(21) Two Hour Load Test Data initially, then approximately every 1/2 hour. (CR 94-2525) _____

5.7.9 At CP003, Record the time and date that DG 11(21) load was raised to greater than 5800 KW, and reactive power was raised to greater than 3400 KVAR.

Time __________ Date __________ _____

Table 1, DG 11(21) Two Hour Load Test Data

DG Load Elapsed

Time (hours)

Time KW 5800 to 5950

(5900 nominal)

KVAR 3400 to 3800

(3600 nominal)

DG Voltage

3744 to 4576 V DG

Frequency 58.8 to 61.2 Hz

0

+ ½

+ 1

+ 1½

+ 2

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5.7.10 WHEN at least 2 hours have elapsed from the time recorded in Step 5.7.9, THEN record the time and date:

Time __________ Date __________ _____

5.7.11 Verify the DG load, reactive power, voltage and frequency values recorded in Table 1, DG 11(21) Two Hour Load Test Data are within the following specified limits:

• Load - between 5800 KW and 5950 KW (nominal 5900 KW) _____

• Voltage - between 3744 V and 4576 V _____

• Reactive Power - between 3400 KVAR and 3800 KVAR (nominal 3600 KVAR) _____

• Frequency - 60 ± 1.2 Hz (58.8 - 61.2 Hz) _____

NOTE

Technical Specification 4.8.1.1.2.e.7 specifies that during the last 22 hours of the twenty-four hour load test, the generator SHALL be loaded to between 5000 and 5500 KW. For conservatism, the DG load should be maintained between 5100 and 5400 KW to ensure compliance with Technical Specification 4.8.1.1.2.e.7. (CR 94-2525)

5.7.12 Reduce DG 11(21) load as follows:

NOTE

Steps 5.7.12.1 through 5.7.12.3 should be performed concurrently to obtain desired DG KW, KVAR and VOLTAGE.

5.7.12.1 Using the DG 11(21) “GOV” switch, lower

DG load to between 5100 KW and 5400 KW (nominal 5250 KW). (CR 94-2525) _____

5.7.12.2 Using the DG 11(21) “VOLT ADJ” switch, lower DG Reactive Power to between 0 and 500 KVAR (200 KVAR nominal). _____

5.7.12.3 IF UAT is supplying Train A 4.16 KV Bus, THEN manually adjust Auxiliary Bus voltage by using UAT Load Tap Changer “VOLT ADJUST (VOLTAGE ADJUST)” to “RAISE” or “LOWER” to ensure bus voltage is between 4120 V - 4309 V on Train A 4.16 KV Bus E1A(E2A). (CP010) _____

AC

AC

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CAUTION

Automatic Operation of the UAT Load Tap Changer should be anticipated anytime the “MODE SELECT (MODE SEL)” switch is placed in “AUTO”.

NOTE

• The UAT Load Tap Changer is normally in “AUTO”.

• Verifying “RAISE” and “LOWER” lights extinguished on the UAT “TAPCHANGER CONTROL” prior to placing the UAT LTC in “AUTO” ensures the UAT LTC does not overcorrect when placed back in “AUTO”.

• Maintaining 4.16 KV bus voltage between 4120 and 4309 V ensures the respective ESF 480 V load centers are maintained within the Technical Specification limits. The UAT LTC will automatically control voltage between 4120 and 4309 V in “AUTO”.

• Technical Specification ESF Bus voltage limits are 3.92 to 4.4 KV as indicated at CP003 on “XFMR E1A(E2A) VOLTS”.

• Technical Specification ESF 480 V LC voltage limits are 443 – 507 volts as indicated locally at the respective load centers.

• Changes to the UAT Load Tap Changer position should be made slowly.

• Depending on plant conditions, lowering the voltage below 4000 VAC could cause the ESF Diesel Generator to start and load on the ESF bus and trip the 4.16 KV feeder breaker to the bus if the Degraded or Undervoltage setpoints are reached.

5.7.13 IF the UAT is supplying Train A 4.16 KV Bus, THEN perform

the following:

5.7.13.1 Manually adjust Auxiliary Bus voltage by using UAT Load Tap Changer “VOLT ADJUST (VOLTAGE ADJUST)” to “RAISE” or “LOWER”, as applicable, until the following conditions are established:

• The “RAISE” and “LOWER” lights on the UAT “TAPCHANGER CONTROL” panel are extinguished. (Inside CP007 on Back Wall) _____

• 4.16 KV bus voltage is 4120 – 4309 V. _____

• 480 V LC bus voltage is 443 – 507 V. _____

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5.7.13.2 Place the UAT Load Tap Changer “MODE SELECT (MODE SEL)” switch in “AUTO”. _____

5.7.13.3 IF in Modes 1-4, THEN notify the Shift Manager to evaluate exiting Technical Specification LCO 3.8.1.1.a, if applicable. _____

5.7.14 Record the time and date that DG 11(21) load was lowered to between 5100 KW and 5400 KW, and reactive power was lowered to between 0 and 500 KVAR (200 KVAR nominal).

Time __________ Date __________ _____

NOTE

Momentary transients outside of 5100 KW to 5400 KW due to changing conditions on the grid SHALL NOT invalidate the test. (Technical Specification 4.8.1.1.2.e.7)

5.7.15 Continue to operate DG 11(21) for at least 22 hours while maintaining (adjust as necessary) the following parameters:

• Load between 5100 KW and 5400 KW (5250 KW nominal)

• Reactive Power between 0 and 500 KVAR (nominal 200 KVAR)

Record the required information on Table 2, DG 11(21) Twenty-Two Hour Load Test Data initially, then approximately every 1/2 hour. (CR 94-2525) _____

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Table 2, DG 11(21) Twenty-Two Hour Load Test Data

DG Load Elapsed Time

(hours) Time KW

5100 to 5400 (nominal 5250)

KVAR 0 to 500

(nominal 200)

DG Voltage

3744 to 4576 V DG


0

+ ½

+ 1

+ 1½

+ 2

+ 2½

+ 3

+ 3½

+ 4

+ 4½

+ 5

+ 5½

+ 6

+ 6½

+ 7

+ 7½

+ 8

+ 8½

+ 9

+ 9½

+ 10

+ 10½

+ 11

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Table 2, DG 11(21) Twenty-Two Hour Load Test Data (continued)

DG Load Elapsed Time

(hours) Time KW

5100 to 5400 (nominal 5250)

KVAR 0 to 500

(nominal 200)

DG Voltage

3744 - 4576 V DG


+ 11½

+ 12

+ 12½

+ 13

+ 13½

+ 14

+ 14½

+ 15

+ 15½

+ 16

+ 16½

+ 17

+ 17½

+ 18

+ 18½

+ 19

+ 19½

+ 20

+ 20½

+ 21

+ 21½

+ 22

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5.7.16 WHEN at least 22 hours have elapsed from the time recorded in Step 5.7.14, THEN record the time and date:

Time __________ Date __________ _____

NOTE

The DG reactive power test data (KVAR) recorded in Table 2 and verified in Step 5.7.17 is FOR INFORMATION ONLY and is NOT Acceptance Criteria. The indicated 0 to 500 KVAR (nominal 200 KVAR) limitation is based on the requirements of CREE 11-17472-59 as a required measure for maintaining the UAT LTC in “AUTO” during the 22 hour portion (5100 to 5400 KW) of the 24 hour load test.

5.7.17 Verify the DG load, reactive power, voltage and frequency values

recorded in Table 2, DG 11(21) Twenty-Two Hour Load Test Data are within the following specified limits:

• Load - between 5100 KW and 5400 KW _____

• Voltage - between 3744 V and 4576 V _____

• Reactive Power - between 0 and 500 KVAR (nominal 200 KVAR) _____

• Frequency - 60 ± 1.2 Hz (58.8 - 61.2 Hz) _____

NOTE

• Step 5.8.3 SHALL be performed within 5 minutes of the time recorded in Step 5.7.19.

• Performance of the DG Post Run Checklist and FOST Accumulated Water Check/Removal following DG shutdown are NOT required prior to the performance of Section 5.8, DG Hot Restart Test.

• DG 11(21) unloading should be accomplished within 15 minutes during the performance of Step 5.7.18.

5.7.18 At CP003, Unload and Stop DG 11(21) per Section 5.10,

DG Unloading, and Section 5.11, DG Shutdown. _____

5.7.19 At DG 11(21), Record the time and date the DG shaft stops rolling:

Time __________ Date __________ _____

5.7.20 Perform Section 5.8, DG Hot Restart Test. _____

AC

AC

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NOTE

• Step 5.8.3 SHALL be performed within 5 minutes of the time recorded in Step 5.7.19.

• IF Section 5.8, DG Hot Restart Test is NOT completed satisfactorily, THEN it is NOT necessary to complete the preceding 24 hour run. Instead the DG shall be operated at 100% loading per Section 5.9 for a minimum of 2 hours or until operating temperature has stabilized. IF this occurs, THEN this procedure should be re-entered at Step 5.7.17, following establishment of the above specified operating conditions.

• Performance of the DG Post Run Checklist and FOST Accumulated Water Check/Removal following DG shutdown are NOT required prior to the performance of Section 5.8, DG Hot Restart Test.

• IF in Modes 5, 6, or Defueled, THEN the “MODE SELECTOR” switch at “NSSS SSPS ACTUATION TRAIN A 3Z101(2)ZRR002” is NOT required to be in “OPERATE” for performance of Section 5.8, DG Hot Restart Test, unless otherwise required by 0PSP03-DG-0013 (Standby Diesel 11(21) LOOP-ESF Actuation Test).

5.8 DG Hot Restart Test

5.8.1 Establish communications between the Main Control Room and locally at DG 11(21). _____

NOTE

IF the recorder is being used at ZLP102, THEN the recorder may be stopped approximately 20 seconds following start of the DG, unless otherwise required for performance of 0PSP03-DG-0007 (Standby Diesel 11(21) LOOP Test) or 0PSP03-DG-0013 (Standby Diesel 11(21) LOOP-ESF Actuation Test).

5.8.2 WHEN directed by Control Room personnel, THEN ensure the

recorder is started at 100 mm/sec. _____

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NOTE

• IF in Modes 1 through 4, THEN in Step 5.8.3 DG 11(21) SHALL be started by depressing the DG 11(21) “EMER START” push button since 0PSP03-DG-0007 (Standby Diesel 11(21) LOOP Test) and 0PSP03-DG-0013 (Standby Diesel 11(21) LOOP-ESF Actuation Test) SHALL NOT be performed in Modes 1 through 4.

• Steps 5.8.3 and 5.8.4 SHALL be performed concurrently.

• DG 11(21) will be started during performance of Step 5.8.3.

5.8.3 Start DG 11(21) utilizing ONE of the following methods:

5.8.3.1 At CP003, momentarily depress the DG 11(21) “EMER START” push button. _____

5.8.3.2 IF in Modes 5, 6, or Defueled, THEN Initiate a DG 11(21) start signal from 0PSP03-DG-0007 (Standby Diesel 11(21) LOOP Test). _____

5.8.3.3 IF in Modes 5, 6, or Defueled, THEN Initiate a DG 11(21) start signal from 0POP03-DG-0013 (Standby Diesel 11(21) LOOP ESF Actuation Test). _____

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NOTE

Illumination of the blue READY FOR LD light SHALL NOT be utilized as an indication of DG speed, voltage and frequency. The blue READY FOR LD light provides indication that DG speed is ≥ 540 rpm (54 Hz) and generator voltage is ≥ 3955 V. (CP003)

5.8.4 At CP003, Monitor the time for the DG to reach rated speed, voltage

and frequency by performing the following:

5.8.4.1 WHEN the diesel start signal is initiated, THEN start the stopwatch. _____

5.8.4.2 WHEN the following DG operating parameters are established, THEN stop the stopwatch: _____

• Voltage - 4160 ± 416 V (3744 - 4576 V)

• Frequency - 60 ± 1.2 Hz (58.8 - 61.2 Hz)

NOTE

WHEN the diesel is started per 0PSP03-DG-0007, Standby Diesel 11(21) LOOP Test, THEN the Acceptance Criteria for Step 5.8.4.3 SHALL be per 0PSP03-DG-0007, Standby Diesel 11(21) LOOP test.

5.8.4.3 Record the time for DG voltage to be within 3744 V

and 4576 V, and frequency to be within 58.8 Hz and 61.2 Hz. _____

__________ seconds _____

Acceptance Criteria: < 10 seconds

5.8.4.4 Record DG 11(21) steady state voltage:

__________ V _____

Acceptance Criteria: 4160 ± 416 V (3744 – 4576 V)

5.8.4.5 Record DG 11(21) steady state frequency:

__________ Hz _____


AC

AC

AC

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5.8.5 Record the time and date DG 11(21) was started:

Time __________ Date __________ _____

5.8.6 At CP022, Verify DG 11(21) “EMER FAN 11A(21A)” started. _____

5.8.7 At CP022, Verify DG 11(21) “NORMAL FAN 11A(21A)” stopped. _____

NOTE

• Restoration and Documentation Step 5.14.11 may be performed at any time following completion of Step 5.8.8.

• The recorder may be stopped approximately 20 seconds following start of the DG, unless otherwise required for performance of 0PSP03-DG-0007 (Standby Diesel 11(21) LOOP Test) or 0PSP03-DG-0013 (Standby Diesel 11(21) LOOP-ESF Actuation Test).

5.8.8 WHEN desired, THEN stop the recorder. _____

5.8.9 ENSURE the recorder trace is labeled with the procedure number, step number, date of test, time of test, recorder operator name(s), recorder scaling, recorder speed, channel identification, and any additional pertinent information. _____

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NOTE

IF DG 11(21) was started per 0PSP03-DG-0007 (Standby Diesel 11(21) LOOP Test) or 0PSP03-DG-0013 (Standby Diesel 11(21) LOOP-ESF Actuation Test), THEN N/A SHALL be recorded in Steps 5.8.10 through 5.8.17. Shutdown of DG 11(21) will be performed per the respective surveillance test procedure.

5.8.10 At CP003, Momentarily depress the DG 11(21) “RESET” push

button to ensure the non-emergency trip logic reset. _____

NOTE

Prior to releasing DG 11(21) from the Emergency Mode, the MASTER TRIP CIRCUIT “RESET” light should be verified to be illuminated. IF the DG is released from Emergency Mode AND the MASTER TRIP CIRCUIT “RESET” light is NOT illuminated, THEN the DG will trip.


illuminated. _____



5.8.14 WHEN at least 5 minutes have elapsed from the time recorded in Step 5.8.5, THEN perform the following:

5.8.14.1 Record the time and date:

Time __________ Date __________ _____

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NOTE

• WHEN DG 11(21) Control Switch is turned to the “STOP” position, THEN the DG will go through an approximate 5 minute cooldown period and stop.

• IF DG 11(21) received a non-emergency trip while in the Emergency Mode, THEN the DG will immediately stop (i.e., no cooldown cycle) when the DG 11(21) control switch is placed in the “STOP” position, even if the non-emergency trip was reset.

5.8.15 Stop DG 11(21) by performing the following:

5.8.15.1 Turn DG 11(21) “NORMAL” control switch to the “STOP” position. (CP003) _____

5.8.15.2 Record time DG 11(21) “NORMAL” control switch in “STOP” position:

Time __________ _____

5.8.15.3 WHEN DG 11(21) has entered the cooldown cycle, THEN verify generator voltage decays indicating proper operation of the Generator Exciter Shunt Relay (K-1). (CP003) (SER 91-0023) _____

5.8.15.4 IF generator voltage DOES NOT decay in the cooldown cycle, THEN submit a Condition Report to investigate the cause of failure. _____

5.8.15.5 Record the time and date DG 11(21) was stopped (fuel racks reposition to no-fuel):

Time __________

Date __________ _____

5.8.16 WHEN DG 11(21) has stopped, THEN perform the following:

5.8.16.1 Stop the “EMER FAN 11A(21A)”. (CP022) _____

5.8.16.2 Start the “NORMAL FAN 11A(21A)”. (CP022) _____

5.8.17 GO TO Section 5.14, Restoration and Documentation. _____

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NOTE

All switches in Section 5.9 are located on Control Room Panel CP003 unless otherwise specified.

5.9 DG Loading

5.9.1 IF the DG 11(21) is secured, THEN start the DG per 0POP02-DG-0001 [Emergency Diesel Generator 11(21)]. _____

5.9.2 Ensure the “DG 11(21) VOLT METER SEL” switch in the “A-B” position to coincide with the generator phases supplying the synchroscope. _____

NOTE

WHEN the “ENGINE START MODE” switch is in the intermediate position between “IDLE” and “RATED” with the diesel running, THEN the diesel speed will start to ramp down at a rate of 10 rpm per sec. Switching the position of the “ENGINE START MODE” switch should be performed without hesitation. WHEN switching is complete, THEN the diesel will return to its original setpoint.

5.9.3 Ensure “ENGINE START MODE” switch is in the “IDLE” position.

(ZLP102) _____

5.9.4 Adjust the generator output voltage approximately 200 volts from Nominal Generator voltage in both directions (approximately 4000 volts to 4400 volts) using the Diesel Generator 11(21) “VOLT ADJ” switch to ensure proper operation of the voltage regulator. _____

5.9.5 Adjust generator frequency 0.5 Hz from Nominal Generator frequency in both directions (approximately 59.5 Hz to 60.5 Hz) using the DG 11(21) “GOV” switch to ensure proper operation of the electro-hydraulic governor. _____

5.9.6 Place DG 11(21) “SYNCHROSCOPE” switch in the “ON” position. _____

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NOTE

Steps 5.9.7 and 5.9.8 SHALL be performed by two Operators as follows: (References 7.4.19 and 7.4.25)

• One Operator SHALL read the procedure steps, ensure the steps are correctly performed, and initial completed steps.

• One Operator SHALL perform the task.

5.9.7 Perform the following, as necessary, to obtain the specified

DG 11(21) operating conditions: _____

• Adjust engine speed using the DG 11(21) “GOV” control switch until the synchroscope is moving slow in the “FAST” direction.

• Adjust the DG 11(21) output voltage using the DG 11(21) “VOLT ADJ” switch until DG 11(21) voltage is slightly higher than “BUS E1A(E2A) VOLTS”.

• Monitor the DG 11(21) “VOLTAGE” meter for all three phases of voltage.

NOTE

It is recommended that as a minimum, 100 to 200 KW load be picked up immediately after closing DG 11(21) Output Breaker to ensure the DG does NOT trip on reverse power.

5.9.8 WHEN the needle on the synchroscope is at the 11:55 position AND

the synchroscope is moving slow in the “FAST” direction, THEN close DG 11(21) “DG OUTP BKR”. _____

5.9.9 Place the “SYNCHROSCOPE” switch in the “OFF” position. _____

5.9.10 Monitor all three phases of voltage and current using the DG 11(21) “VOLTAGE” meter and “CURRENT” meter. _____

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NOTE

Steps 5.9.11 and 5.9.12 should be performed concurrently to obtain the desired DG KW and KVAR.

5.9.11 Using the DG 11(21) “GOV” switch, perform the following,

as applicable:

5.9.11.1 IF Section 5.4, 5.5 or 5.6 is being performed, THEN raise DG load to the required value using the recommended loading rates specified in Step 5.9.13, or at a rate specified by the Unit Supervisor or Shift Manager. (CR 94-2525) _____

5.9.11.2 IF Section 5.7 is being performed, THEN raise DG load to the required value using the recommended loading rates specified in Step 5.9.14, or at a rate specified by the Unit Supervisor or Shift Manager. (CR 94-2525) _____

NOTE

Generator Reactive Power (KVAR) should be maintained positive while performing Step 5.9.12.

5.9.12 Using the DG 11(21) “VOLT ADJ” switch, perform the following,

as applicable:

5.9.12.1 IF Section 5.4, 5.5 or 5.6 is being performed, THEN maintain DG Reactive Load between 0 and 500 KVAR (200 KVAR nominal) while loading the diesel generator in Step 5.9.13. _____

5.9.12.2 IF Section 5.7 is being performed, THEN adjust DG Reactive Load to maintain the indicated KVAR values while loading the diesel generator in Step 5.9.14, or at a rate specified by the Unit Supervisor or Shift Manager. _____

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NOTE

• The recommended loading rates specified in Step 5.9.13 may be waived at the discretion of the Unit Supervisor or Shift Manager, for the purpose of expediting the DG 11(21) Operability Test, to satisfy the requirements of a Limiting Condition for Operation.

• During DG 11(21) Loading, the recommended 5 minute LOAD DURATION at 0% ENGINE LOAD may be with the DG output breaker open or with the DG output breaker closed and the DG operating at minimum load.

• Momentary transients outside of the specified load bands due to changing conditions on the grid SHALL NOT invalidate the test.

5.9.13 IF Section 5.4, 5.5 or 5.6 is being performed, THEN load DG 11(21) to the value specified in Step 5.4.1, 5.5.1 OR 5.6.1, as applicable, per the loading rates of Table 3, or as directed by the Unit Supervisor or Shift Manager. _____

Table 3. Recommended DG Loading Rates for Sections 5.4, 5.5 and 5.6

TIME LOAD REACHED ENGINE LOAD

LOAD DURATION GEN LOAD

GEN REACTIVE LOAD (KVAR)

Step 5.4.1 Step 5.5.1 Step 5.6.1

0 % < 5 MIN 100 – 200 KW

0 – 500 KVAR (200 KVAR

nominal)

25 % 10 MIN 1375 KW 0 – 500 KVAR

(200 KVAR nominal)

50 % 10 MIN 2750 KW 0 – 500 KVAR

(200 KVAR nominal)

75 % 10 MIN 4125 KW 0 – 500 KVAR

(200 KVAR nominal)

100-110% As specified As specified 0 – 500 KVAR

(200 KVAR nominal)

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NOTE

• The recommended loading rates specified in Step 5.9.14 may be waived at the discretion of the Unit Supervisor or Shift Manager, for the purpose of expediting the DG 11(21) Operability Test, to satisfy the requirements of a Limiting Condition for Operation.

• During DG 11(21) Loading, the recommended 5 minute LOAD DURATION at 0% ENGINE LOAD may be with the DG output breaker open or with the DG output breaker closed and the DG operating at minimum load.

• Momentary transients outside of the specified load bands due to changing conditions on the grid SHALL NOT invalidate the test.

5.9.14 IF Section 5.7 is being performed, THEN load DG 11(21) to the value specified in Step 5.7.4 per the loading rates of Table 4, or as directed by the Unit Supervisor or Shift Manager. _____

Table 4. Recommended DG Loading Rates for Section 5.7

ENGINE LOAD

LOAD DURATION GEN LOAD

GEN REACTIVE LOAD (KVAR)

TIME LOAD REACHED

Step 5.7.4

0 % < 5 MIN 100 – 200 KW 0 – 500 KVAR (200 KVAR nominal)

25 % 10 MIN 1375 KW 700 – 1100 KVAR (900 KVAR nominal)



100-110% As specified 5800 – 5950 KW (5900 KW nominal)

3400 – 3800 KVAR (3600 KVAR nominal)

5.9.15 RETURN TO Step 5.4.1, 5.5.1, 5.6.1, OR 5.7.4, as applicable. _____

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NOTE

• All switches in Section 5.10 are located on Control Room Panel CP003, unless otherwise specified.

• Steps 5.10.1 and 5.10.2 should be performed concurrently to obtain desired DG KW and KVAR.

5.10 DG Unloading

5.10.1 Using the DG 11(21) “GOV” switch, lower DG load to 100–200 KW per the recommended unloading rates specified in Step 5.10.3, or at a rate specified by the Unit Supervisor or Shift Manager. _____

NOTE

Generator Reactive Power (KVAR) should be maintained positive while performing Step 5.10.2.

5.10.2 Using the DG 11(21) “VOLT ADJ” switch, maintain DG Reactive

Load between 0 and 500 KVAR (200 KVAR nominal) while unloading the diesel generator in Step 5.10.3. _____

5.10.3 Unload DG 11(21) per Table 5, or as directed by the Unit Supervisor or Shift Manager. _____

Table 5. Recommended DG Unloading Rates

ENGINE LOAD LOAD DURATION GEN LOAD GEN REACTIVE

LOAD (KVAR) TIME LOAD REACHED




0 % < 5 MIN 100 – 200 KW 0 – 500 KVAR (200 KVAR nominal)

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5.10.4 IF DG Slave Relay Test is being performed as part of this surveillance procedure, THEN perform the following, OTHERWISE record N/A in Steps 5.10.4.1 through 5.10.4.6:

NOTE

• Steps 5.10.4.1 through 5.10.4.6 test Slave Relay K828. Operation of Slave Relay K828 will trip the DG output breaker without placing the DG in Emergency Mode.

• The test switches and indications referred to in Steps 5.10.4.2, 5.10.4.5 and 5.10.4.6 are located at “NSSS SAFEGUARD TST CAB TRAIN A 3Z101(2)ZRR003”, “CABINET NO. 1”. This cabinet will be referred to as ZRR003-1 during the performance of the respective steps.

5.10.4.1 Record N/A in Step 5.10.5. _____

5.10.4.2 At ZRR003-1, WHEN directed by Control Room personnel, THEN turn “SAFETY INJECTION” switch “S106” to “PUSH TO TEST” and momentarily depress, then release and return to “NORMAL”. _____


5.10.4.3 At CP003, Verify DG 11(21) “DG OUTP BKR” opened. _____

5.10.4.4 At CP003, Verify DG 11(21) NOT tripped. _____

5.10.4.5 At ZRR003-1, WHEN directed by Control Room personnel, THEN Turn “RESET” switch “S121” to “RESET” and return to “NORMAL”. _____


5.10.4.6 At ZRR003-1, Verify red test light “10-T1” is extinguished. _____

5.10.5 Open DG 11(21) “DG OUTP BKR”. _____


Perform _____ Ind. Verif

AC

AC

DV

DV

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NOTE

WHEN the “ENGINE START MODE” switch is in the intermediate position between “IDLE” and “RATED” with the diesel running, THEN the diesel speed will start to ramp down at a rate of 10 rpm per sec. Switching the position of the “ENGINE START MODE” switch should be performed without hesitation. WHEN switching is complete, THEN the diesel will return to its original setpoint.

5.10.7 Ensure the “ENGINE START MODE” switch in the

“RATED” position. (ZLP102) _____ Perform

_____ Ind. Verif

5.10.8 GO TO Section 5.11, DG Shutdown _____

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5.11 DG Shutdown

NOTE

• WHEN DG 11(21) Control Switch is turned to the “STOP” position, THEN the DG will go through an approximate 5 minute cooldown period and stop.

• IF DG 11(21) received a non-emergency trip while in the Emergency Mode, THEN the DG will immediately stop (e.g. no cooldown cycle) when the DG 11(21) control switch is placed in the “STOP” position, even if the non-emergency trip was reset.

5.11.1 Stop DG 11(21) by performing the following:

5.11.1.1 Turn DG 11(21) “NORMAL” control switch to the “STOP” position. (CP003) _____

5.11.1.2 Record time DG 11(21) “NORMAL” control switch in “STOP” position:

Time __________ _____

5.11.1.3 WHEN DG 11(21) has entered the cooldown cycle, THEN verify generator voltage decays indicating proper operation of the Generator Exciter Shunt Relay (K-1). (CP003) (SER 91-0023) _____

5.11.1.4 IF generator voltage DOES NOT decay in the cooldown cycle, THEN submit a Condition Report to investigate the cause of failure. _____

5.11.1.5 Record the time and date DG 11(21) was stopped (fuel racks reposition to no-fuel):

Time __________

Date __________ _____

5.11.2 WHEN DG 11(21) has stopped, THEN perform the following:

5.11.2.1 Stop the “EMER FAN 11A(21A)”. (CP022) _____

5.11.2.2 Start the “NORMAL FAN 11A(21A)”. (CP022) _____

5.11.3 IF Section 5.8 DG Hot Restart is to be performed, THEN return to Step 5.7.19. _____


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5.12 DG Post Run Checklist

CAUTION

IF an Emergency Start signal is locked in when an Emergency Trip is reset, THEN the DG will restart. Depressing the “Release” button PRIOR to resetting the trip will prevent restart.

NOTE

• Sections 5.12 and 5.13 may be performed concurrently, or in any order.

• Steps 5.12.1 through 5.12.12 may be performed concurrently, or in any order.

5.12.1 Ensure the Train A Load Sequencer reset. _____

AC

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CAUTION

• IF DGFOST 11(21) level lowers to less than 60,500 gallons, THEN the DG SHALL be declared inoperable. (Technical Specification 3.8.1.1.b, 3.8.1.2.b, 3.8.1.3.b)

• The DGFOST magnetic sightglass takes approximately 1 hour to stabilize following level change evolutions.

• “1(2)-LI-9109B DIESEL FUEL OIL STORAGE TANK #11(21) LEVEL INDICATOR” (55' DGB outside of S. tank room door), LI-9109 (CP003) meter, Plant Computer point DOLA9109 or DGFOST magnetic sightglass may be used at the discretion of the SM/US.

5.12.2 IF DG 11(21) is to be declared OPERABLE, THEN ensure DGFOST 11(21) contains greater than or equal to 60,500 gallons, as follows: (Technical Specification 4.8.1.1.2.a.1)

5.12.2.1 Record DGFOST 11(21) level from one of the following: _____

• LI-9109 (CP003) __________gal • Plant Computer Point DOLA9109 __________gal • “1(2)-LI-9109B DIESEL FUEL OIL

STORAGE TANK #11(21) LEVEL INDICATOR” (55' DGB Outside of S. Tank Room Door) __________gal

5.12.2.2 IF the DGFOST magnetic sightglass is desired to be used to obtain FOST level, THEN perform the following:

a. Ensure at least 1 hour has elapsed following either diesel run or fuel oil storage tank fill. _____

b. Record DGFOST 11(21) level. “1(2)DO-LI-9110B DIESEL GENERATOR #11(21) FUEL OIL STORAGE TANK LEVEL INDICATOR” (Magnetic Sightglass, 55 ft DGB Exhaust Silencer Area)

__________ gallons _____

5.12.2.3 Ensure DGFOST 11(21) contains greater than or equal to 60,500 gallons. _____

Acceptance Criteria: ≥ 60,500 gallons

AC

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5.12.3 Verify Annunciator Lampbox 102 Windows are either extinguished, or the alarm condition evaluated. _____

5.12.4 Verify the following indications exist on ZLP102, or the condition evaluated:

• MASTER TRIP CIRCUIT “RESET” amber light - ON _____

• MASTER TRIP CIRCUIT “TRIPPED” green light - OFF _____

• “EMERGENCY MODE” white light - OFF _____

• “DG AVAILABLE FOR EMERGENCY” white light - ON _____

• “SHUTDOWN BYPASS” red light - ON _____

• “LOCAL MODE” white light - OFF _____

• “OFF MODE” white light - OFF _____

• “REMOTE MODE” white light - ON _____

• SEQUENCE INDICATION “STOP” green light - ON _____

• SEQUENCE INDICATION “CRANK” amber light - OFF _____

• SEQUENCE INDICATION “READY TO LOAD” red light - OFF _____

• SEQUENCE INDICATION “RUNNING LOADED” red light - OFF _____

• “DC POWER ON CIRCUIT 1” white light - ON _____

• “DC POWER ON CIRCUIT 2” white light - ON _____

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NOTE

The Control Room SHALL be notified prior to resetting any flags on ZLP101.

5.12.5 Ensure any existing flags at ZLP101 reset. _____

5.12.6 IF Annunciator Lampbox 102, Window C-1, “D.G. LOW AIR PRESSURE” is illuminated due to previous securing of the air receivers AND it is desired to reset this alarm, THEN perform 0POP02-DG-0001 [Emergency Diesel Generator 11(21)], Repressurizing Instrument Header Lineup 7. _____

NOTE

Sufficient time SHALL be allowed for the air intake filter oil to drain to the filter reservoir prior to verifying air intake filter oil level. Failure to allow adequate time for the air intake filter oil to drain down will result in inconsistent and erroneous readings.

5.12.7 Ensure the oil level in the DG 11(21) Air Intake Filter above

the bullseye fill line. (55 ft DGB, Filter Room) _____

5.12.8 Ensure the oil level in the DG 11(21) Generator Outboard Bearing visible in the bullseye. (Generator Pedestal Bearing) _____

NOTE

• Verification that "1(2)-DG-MDA-0134, DIESEL AIR INTAKE BUTTERFLY VALVE" is RESET AND FULLY LATCHED SHALL be performed VISUALLY.

• IF "1(2)-DG-MDA-0134, DIESEL AIR INTAKE BUTTERFLY VALVE" is visually verified NOT RESET OR NOT FULLY LATCHED, THEN either of the following methods MAY be utilized to reset the valve:

o Manually reset locally at the turbocharger, or

o Remotely reset by depressing "1(2)-DG-HV-5476F ENGINE OVERSPEED SHUTDOWN AIR RESET VALVE" at the overspeed trip governor.

5.12.9 Ensure DG 11(21) “1(2)-DG-MDA-0134, DIESEL AIR INTAKE BUTTERFLY VALVE” is RESET and FULLY LATCHED at the Turbocharger. (IN 93-096) _____

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5.12.10 Record the respective DG readings in Table 6 (DG Post Run Data). Record any observations or comments in the Remarks Section of the PPDS. _____

Table 6. DG Post Run Data

PARAMETER INSTR READING RANGE

Turbo Lube Oil Pressure PI-5498 (ZLP102) 4 – 13 psig

Engine Lube Oil Pressure PI-5497 (ZLP102) 5 – 15 psig

Jacket Water Stand Pipe Level LG-5400 (NW Skid) ≥ Minus 5 inches

Below Normal

Engine Sump Oil Level LG-5496 (NE Skid) 0 (Blue Line)

± 2 inches

Electro-Mechanical Governor Oil Level

Sightglass (SW Skid)


DG is S/D

Overspeed Governor Oil Level Sightglass (SE Skid)


DG is S/D

Any Visible Leaks Evaluated (Water, Fuel Oil, Lube Oil, Air) N/A Leaks Evaluated

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NOTE

• WHEN the Diesel Generator is NOT running AND jacket water temperature is approximately 175°F, THEN level should be +1 to +7 inches ABOVE the NORMAL mark.

• WHEN the Diesel Generator is NOT running AND jacket water temperature is approximately 120-130°F, THEN level should be adjusted between 3 and 4 inches BELOW the NORMAL mark. (References 7.8.11 and 7.8.12)

5.12.11 ENSURE jacket water standpipe level adjusted for the applicable

operating condition as follows: (Reference 7.4.23)

5.12.11.1 IF jacket water standpipe level is low, THEN PERFORM the following:

a. OPEN "1(2)-JW-0091 J.W. M/U ISOL VALVE". (W of Jacket Water Standpipe) _____

b. WHEN the desired jacket water standpipe level is obtained, THEN CLOSE "1(2)-JW-0091 J.W. M/U ISOL VALVE" _____ Perform

_____ Ind. Verif

5.12.11.2 IF jacket water standpipe level is high, THEN PERFORM the following:

a. OPEN "1(2)-JW-0005 J.W. STANDPIPE DRN VALVE". (SW of JW Cooler Under Grate) _____

b. WHEN the desired jacket water standpipe level is obtained, THEN CLOSE "1(2)-JW-0005 J.W. STANDPIPE DRN VALVE". _____ Perform

_____ Ind. Verif

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5.12.12 IF Jacket Water Stand Pipe Level additions were performed, THEN RECORD on 0OOI01-OL-0005, Operations Logs - Diesel Generator. _____

5.12.13 Record completion of this checklist on the Logs, 0OOI01-OL-0005 (Operations Logs – Diesel Generator). _____


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NOTE

• Sections 5.12 and 5.13 may be performed concurrently, or in any order.

• IF Section 5.13 is NOT required to be performed, THEN N/A SHALL be recorded in the Initials column.

• Steps 5.13.1 and 5.13.2 may be performed concurrently, or in any order.

5.13 DGFOST Accumulated Water Check/Removal

5.13.1 IF the DG operated for 1 hour or greater OR the 31 day DGFOST 11(21) check for, and removal of accumulated water is required, THEN perform the following. (Technical Specification 4.8.1.1.2.b) _____

5.13.1.1 Obtain a clear sample container (plastic bag) for use in determining the presence of accumulated water in the DGFOST 11(21) sample. _____

NOTE

The quantity of fuel oil drained during the sample process should be minimized, in order to reduce the amount of oily waste.

5.13.1.2 Slowly crack open “1(2)-DO-0043 FUEL OIL

STORAGE TANK DRAIN VALVE” to start the fuel oil sample flow. (55 ft DGB, FOST Room) _____

NOTE

IF fuel oil samples indicate the presence of excessive amounts of water, THEN a Condition Report SHALL be submitted to determine the source of water and take corrective action.

5.13.1.3 Take a fuel oil sample from “1(2)-DO-0043 FUEL OIL

STORAGE TANK DRAIN VALVE”. (55 ft DGB, FOST Room) _____

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5.13.1.4 Visually check the fuel oil sample for the presence of accumulated water. _____

5.13.1.5 IF the fuel oil sample indicates the presence of any accumulated water, THEN continue to drain fuel oil and take fuel oil samples. _____

5.13.1.6 WHEN DGFOST 11(21) samples indicate the absence of accumulated water, THEN close “1(2)-DO-0043 FUEL OIL STORAGE TANK DRAIN VALVE” (55 ft DGB, FOST Room) _____


5.13.2 IF it is desired to drain the Fuel Oil Storage Tank 11(21) Oily Waste System area drain header, THEN perform the following:

5.13.2.1 Slowly open the following Fuel Oil Storage Tank 11(21) Oily Waste System area drain valves:

• “1(2)-PD-0378 DIESEL GENERATOR #11(21) FOST AREA DRAIN VALVE” (30 ft DGB, W Wall) _____


AC

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5.13.2.2 WHEN the Fuel Oil Storage Tank 11(21) Oily Waste System area drain header is drained, THEN close the following valves:





5.13.3 Dispose of fuel oil samples in accordance with approved site procedure. _____

5.13.4 Record the performance of DGFOST 11(21) accumulated water check/removal in 0PSP03-ZQ-0025 (Diesel Generator Starting Classification). _____


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5.14 Restoration and Documentation

NOTE

Steps 5.14.1 through 5.14.18 may be performed concurrently, or in any order.

5.14.1 Notify the Shift Manager that testing is complete. _____

5.14.2 Ensure DG 11(21) start information is recorded in 0PSP03-ZQ-0025 (Diesel Generator Starting Classification). (SPR 890723) _____

5.14.3 Ensure Section 5.13, DGFOST Accumulated Water Check/Removal performed and recorded in 0PSP03-ZQ-0025 (Diesel Generator Starting Classification) if required. (Technical Specification 4.8.1.1.2.b) _____

5.14.4 Ensure DG 11(21) in Standby per Section 5.12, DG Post Run Checklist. _____

5.14.5 IF the 4160V emergency bus feeds were aligned to support EDG 24 hour surveillance testing, THEN the 4160V Emergency Busses may be aligned to be fed as desired by the Shift Manager. Refer to 0POP02-AE-0002 (Transformer Normal Breaker and Switch Lineup). _____

AC

AC

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5.14.6 Ensure the Train R and S “MASTER RELAY DEFEAT SWITCH” (MRDS) and SSPS Actuation Train “MODE SELECTOR” switches identified in Table 10 in the AS FOUND position, or a position as specified by the Unit Supervisor or Shift Manager. Record the AS LEFT Position. _____

Table 10, MRDS and SSPS Switch Position Verification

Switch Nameplate Description AS FOUND

Position (Step 4.3)

AS LEFT Position

(Step 5.14.6) Performed By Verified By

Train R “MASTER RELAY DEFEAT SWITCH”

(ZRR001)

Train S “MASTER RELAY DEFEAT SWITCH”

(ZRR008)

SSPS Actuation Train A “MODE SELECTOR” Switch

(ZRR002)

SSPS Actuation Train B “MODE SELECTOR” Switch

(ZRR004)

SSPS Actuation Train C “MODE SELECTOR” Switch

(ZRR006)

5.14.7 IF test equipment installed per 0PSP03-DG-0013, Standby Diesel 11(21) LOOP-ESF Actuation Test, THEN N/A step 5.14.8. _____

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5.14.8 IF installation of the recorder is NOT required to support additional DG 11(21) testing, THEN perform the following to remove the recorder:

NOTE

• WHEN the plant is in Modes 1 through 4 AND the DG 11(21) “EMER STOP” plunger is placed in the “PULL TO STOP” position, THEN DG 11(21) SHALL be declared inoperable. DG11(21) may be considered functional if a Control Room Operator is stationed to ensure Step 5.14.8.6 is performed to return DG 11(21) to its required safety condition in the event of an ESF actuation. (SPR 933560) (Reference 7.7.14)

• WHEN the plant is in Modes 5, 6, or Defueled AND the DG 11(21) “EMER STOP” plunger is placed in the “PULL TO STOP” position, THEN the DG may be considered operable provided a Dedicated Operator is stationed at the DG 11(21) controls to start the DG, if required. (SPR 933560)

5.14.8.1 Ensure the DG 11(21) “EMER STOP” plunger

placed in the “PULL TO STOP” position. (CP003) (SPR 933560) _____

5.14.8.2 Request I&C Maintenance to remove the following:

• Recorder and voltage/frequency transducer interface from DG 11(21) per Addendum 1, DG 11(21) Recorder Installation/Removal. (SPR 921316) _____

I&C Maintenance

_____ Ind. Verif

• 250 OHM test shunt resistance across the 65GSC 701 Digital Speed Control output. _____

I&C Maintenance

_____ Ind. Verif

5.14.8.3 Request I&C Maintenance to ensure ALL test equipment is removed. _____

I&C Maintenance

_____ Ind. Verif

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5.14.8.4 Momentarily depress the DG 11(21) “RELEASE” pushbutton. (CP003) _____

5.14.8.5 Verify the “EMERGENCY MODE” white light is extinguished to ensure the 1ESL1 and 1ESL2 Emergency Start Latch Relays reset. (ZLP102) _____

5.14.8.6 Place the DG 11(21) “EMER STOP” plunger in the “PUSH TO RESET” position. (CP003) _____

Perform

_____ Ind. Verif

5.14.8.7 Request I&C Maintenance to perform a post-test calibration of the recorder per Addendum 1 [DG 11(21) Recorder Installation/Removal]. (NOT required for Yokagawa recorder.) (SPR 921316) _____

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Initials


5.14.9 Utilizing the recorder voltage and frequency traces obtained in Section 5.3, DG Auto Start on ESF Actuation, perform the following:

5.14.9.1 Ensure the recorder trace is labeled with the procedure number, step number, date of test, time of test, recorder operator name(s), recorder scaling, recorder speed, channel identification, and any additional pertinent information. _____

5.14.9.2 Record the time for DG voltage to be within 3744 V and 4576 V, and frequency to be within 58.8 Hz and 61.2 Hz.

__________ seconds _____ Acceptance Criteria: ≤ 10 seconds

5.14.9.3 Record DG 11(21) steady-state voltage:

__________ V _____ Acceptance Criteria: 4160 ± 416 V (3744 - 4576 V)


__________ Hz _____ Acceptance Criteria: 60 ± 1.2 Hz (58.8 - 61.2 Hz)

NOTE

IF in Mode 3, 4, 5, 6 or Defueled, THEN the recorder SHALL NOT be stopped until at least 5 minutes have elapsed since the performance of Step 5.3.7 to ensure the 5 minute operation requirement of Technical Specification 4.8.1.1.2.e.5 is satisfied.

5.14.9.5 IF in Mode 3, 4, 5, 6 or Defueled, THEN verify the

following steady-state DG operating parameters are established and maintained for greater than or equal to 5 minutes following the DG start:

• Voltage - 4160 ± 416 V (3744 - 4576 V) _____

• Frequency - 60 ± 1.2 Hz (58.8 - 61.2 Hz) _____

AC

AC

AC

AC

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5.14.10 Utilizing the recorder voltage and frequency traces obtained in Section 5.6, DG 5500 KW Load Reject, perform the following:


5.14.10.2 Record the maximum DG voltage following the 5500 KW load rejection.

__________ V _____ Acceptance Criteria: ≤ 5262 V

5.14.11 Utilizing the recorder voltage and frequency traces obtained in Section 5.8, DG Hot Restart, perform the following:


5.14.11.2 Record the time for DG voltage to be within 3744 V and 4576 V, and frequency to be within 58.8 Hz and 61.2 Hz.

__________ seconds _____ Acceptance Criteria: ≤ 10 seconds

5.14.11.3 Record DG 11(21) steady-state voltage:

__________ V _____ Acceptance Criteria: 4160 ± 416 V (3744 - 4576 V)


__________ Hz _____ Acceptance Criteria: 60 ± 1.2 Hz (58.8 - 61.2 Hz)

AC

AC

AC

AC

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5.14.12 For the Sections that were performed, compare test data with applicable Section 6.0 Acceptance Criteria. _____

5.14.13 Complete the Test Results Section of the PPDS. _____

5.14.14 Ensure the M&TE Used Section of the PPDS is complete. _____

5.14.15 Ensure required information has been recorded on the M&TE Usage form (WOFWOME) in STP IMPACT for each piece of M&TE used. (SPR 941413 ) _____

5.14.16 Ensure Performer and Verifiers Section of PPDS is complete. _____

5.14.17 Attach the applicable portions of the recorder traces with calibration data to this procedure. _____

5.14.18 IF any problems occurred, THEN initiate Condition Report(s) and log Condition Report number(s) in Remarks section of the PPDS. _____

5.14.19 Forward procedure to the Shift Manager for review. _____

5.14.20 Attach 0OOI01-OL-0005, Operations Logs - Diesel Generator, for System Engineer Review. _____

0PSP03-DG-0016 Rev. 38 Page 83 of 99


6.0 Acceptance Criteria

6.1 DG 11(21) SHALL start from standby condition and accelerate to 600 RPM (nominal) in less than or equal to 10 seconds. The generator voltage SHALL be 3744 to 4576 volts and frequency SHALL be 58.8 to 61.2 Hz within 10 seconds after the start signal. (Steps 5.3.5.3, 5.3.5.4, 5.3.5.5, 5.14.9.2, 5.14.9.3, 5.14.9.4 ) (Technical Specification 4.8.1.1.2.a.2)

6.2 DG 11(21) SHALL start from standby condition and accelerate to 600 RPM (nominal) in less than or equal to 10 seconds. The generator voltage SHALL be 3744 to 4576 volts and frequency SHALL be 58.8 to 61.2 Hz within 10 seconds after the start signal (Steps 5.3.5.3, 5.3.5.4, 5.3.5.5, 5.14.9.2, 5.14.9.3, 5.14.9.4 )This partially satisfies the following requirements:

• SI Manual Initiation Trip Actuating Device Operational Test (TADOT) start of Standby DG. (Technical Specification 4.3.2.1.1.a.4)

• Containment Pressure High-1 SI start of Standby DG ESF Response Time Test. (Technical Specification 4.3.2.2.2.a.9)

• PRZR Pressure-Low SI start of Standby DG ESF Response Time Test. (Technical Specification 4.3.2.2.3.a.9)

• Compensated Steam Line Pressure-Low SI start of Standby DG ESF Response Time Test. (Technical Specification 4.3.2.2.5.a.9)

6.3 DG 11(21) SHALL start on a simulated SI signal, without LOOP, and operate on standby for greater than or equal to 5 minutes. The generator voltage SHALL be 3744 to 4576 volts and frequency SHALL be 58.8 to 61.2 Hz within 10 seconds after the start signal. The steady state generator voltage and frequency SHALL be maintained within these limits for greater than or equal to 5 minutes. (Steps 5.3.5.3, 5.3.5.4, 5.3.5.5, 5.3.6, 5.14.9.2, 5.14.9.3, 5.14.9.4, and 5.14.9.5) (Technical Specifications 4.8.1.1.2.e.5 and 4.3.2.2.2.a.9)

6.4 All tested circuits and devices SHALL operate as indicated. (Steps 5.3.5.3, 5.3.12.1, 5.3.12.2, 5.4.3, 5.4.4, 5.6.5, 5.6.6, 5.10.4.3, 5.10.4.4, and 5.14.9.2) (Technical Specifications 4.3.2.1.1.a.4 and 4.3.2.1.1.c.7)

6.5 When DG 11(21) is operating in the test mode, connected to its bus, a simulated SI signal SHALL override the test mode by: (1) Returning the DG to standby operation (Steps 5.4.3, 5.4.4, 5.4.6, 5.4.7 and 5.4.8), and (2) Automatically energizing the ESF loads with offsite power. (Step 5.4.5) (Technical Specification 4.8.1.1.2.e.10)

0PSP03-DG-0016 Rev. 38 Page 84 of 99



6.6 DG 11(21) SHALL reject a load of greater than or equal to 5500 KW without tripping. The generator voltage SHALL NOT exceed 5262 volts during and following the load rejection. (Steps 5.6.5, 5.6.6 and 5.14.10.2) (Technical Specification 4.8.1.1.2.e.3)

6.7 DG 11(21) SHALL be synchronized, loaded to 5000 to 5500 KW, and operate with a load of 5000 to 5500 KW for at least 60 minutes. (Either Step 5.5.6 OR Steps 5.7.16 AND 5.7.17) (Technical Specification 4.8.1.1.2.a.3)

6.8 DG 11(21) SHALL operate for at least 24 hours. During the first 2 hours the DG SHALL be loaded to between 5700 to 6050 KW (Steps 5.7.10 and 5.7.11). During the remaining 22 hours the diesel SHALL be loaded to between 5000 to 5500 KW (Steps 5.7.16 and 5.7.17). The steady state voltage SHALL be 3744 to 4576 volts, and the steady state frequency SHALL be 58.8 to 61.2 Hz (Steps 5.7.11 and 5.7.17). Within 5 minutes after completing the 24-hour test, a fast start SHALL be performed per the requirements of Technical Specification 4.8.1.1.2.a.2. (Steps 5.8.4.3, 5.8.4.4, 5.8.4.5, 5.14.11.2, 5.14.11.3 and 5.14.11.4) (Technical Specification 4.8.1.1.2.e.7)

6.9 DGFOST 11(21) SHALL contain greater than or equal to 60,500 gallons. (Step 5.12.2.3) (Technical Specification 4.8.1.1.2.a.1)

6.10 At least once per 31 days, and after each operation of the diesel where the period of operation was greater than or equal to one (1) hour, accumulated water SHALL be checked for, and removed from DGFOST 11(21). (Step 5.13.1.6, 5.14.3) (Technical Specification 4.8.1.1.2.b)

6.11 DG 11(21) SHALL be aligned to provide standby power to Emergency Bus E1A(E2A). (Steps 5.4.11, 5.6.11, 5.10.6, 5.12, and 5.14.4) (Technical Specification 4.8.1.1.2.a.4)

0PSP03-DG-0016 Rev. 38 Page 85 of 99



7.0 References

7.1 Technical Specifications

7.1.1 Technical Specification 3.3.2

7.1.2 Technical Specification 3.8.1.1



7.2 Regulatory Guides and Standards

7.2.1 Regulatory Guide 1.9, Rev. 2 (Selection, Design, Qualification, and Testing of Emergency Diesel Generator Units Used as Class 1E Onsite Electric Power Systems at Nuclear Power Plants)

7.2.2 Regulatory Guide 1.108, Rev. 1 (Periodic Testing of Diesel Generator Units Used as Onsite Electric Power Systems at Nuclear Power Plants)

7.2.3 IEEE 387-1977 (IEEE Standard Criteria for Diesel-Generator Units Applied as Standby Power Supplies for Nuclear Power Generating Stations)

7.3 UFSAR

7.3.1 Section 7.3.1 (Nuclear Steam Supply System ESFAS)

7.3.2 Section 8.3 (Onsite Power Systems)

7.3.3 Section 9.5.4 (Diesel Generator Fuel Oil Storage and Transfer)

7.3.4 Section 9.5.5 (Diesel Generator Cooling Water System)

7.3.5 Section 9.5.6 (Diesel Generator Starting System)

7.3.6 Section 9.5.7 (Diesel Generator Lubrication System)

7.3.7 Section 9.5.8 (Diesel Generator Combustion Air Intake and Exhaust System)

7.3.8 Section 9.5.10 (Auxiliary Fuel Oil Storage and Transfer)

7.3.9 Table 16.1-4 (Engineered Safety Features Response Times)

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7.4 Commitments

7.4.1 SPR 890723 (MATS Item 8901689-936) (An Attempted DG Start Was Not Logged As Required)

7.4.2 SPR 900177 (Inadvertent ESF Actuation Due to Inadequate Control of Procedure Performance)

7.4.3 SPR 921000 (“A” Train Containment Valve Isolation Due to “C” Train Radiation Monitoring)

7.4.4 SPR 921316 (Improper Use of Recorders on ESF Diesel Generators)

7.4.5 SPR 930641 (Reactor Trip Caused By Two of Three Trains Actuation Trains in Test)

7.4.6 SPR 941413 (M&TE Issue Sheets Not Completed for Each Use of the Instrument)

7.4.7 SPR 933560 (LER 1-93-023) (Inadvertent ESF Actuation of Standby Diesel Generator 12 During Testing)

7.4.8 SPR 941728 (Operation of ESF Loads Contrary to the Fault Study Analysis During Parallel Operation of the DG)

7.4.9 CR 94-2525 (Improper Calibration Tolerance of Diesel Generator Instrumentation Used for Technical Specification Surveillances)

7.4.10 CR 95-11326 (Implementation of NRC commitments in ST-HL-AE-5203 regarding twenty-four hour diesel run at power)

7.4.11 ST-HL-AE-5141 (Letter to the NRC where WE committed to perform only Technical Specification Surveillances 4.8.1.1.2.e.1 and 4.8.1.1.2.e.7 at power)

7.4.12 CR 95-3749 (Engineering Evaluation to Perform Diesel Testing with the RHR Pump Running)

7.4.13 CREE 96-6171 (Analysis of SDG operation in parallel with the Emergency Transformer)

7.4.14 CREE 96-1619-34 (Use of SDG FOST narrow range level indication to develop a correction factor for the wide range level indication.)

7.4.15 CREE 96-7705-4 (Tripping of 120 VAC incoming AC breaker)

7.4.16 IEC 80-005 (MATS Item 8401237-866) (Emergency DG Lubricating Oil Addition and Onsite Supply)

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7.4.17 IN 93-096 (Improper Reset Causes Emergency Diesel Generator Failures)

7.4.18 SER 91-0023 (LCTS Item 9101272-936) (Emergency Diesel Generator Field Flash Inadvertently Disabled)

7.4.19 SPR 890691 (MATS Item 8901583-936) (ESF DG Was Inadvertently Paralleled Out of Phase During Surveillance Testing)

7.4.20 IEN 91-013 (Inadequate Testing of Emergency Diesel Generators)

7.4.21 IN 83-83 (Use of Portable Radio Transmitters Inside Nuclear Power Plants)

7.4.22 CAQ-S 04-12113-8, Independent verification block for I&C Supervisor

7.4.23 9000430-936 (IR 90-0009), NRC Exit Meeting

7.4.24 CREE 07-13247-1, Recommendation for exceptions to the 10 Deg F differential between Jacket Water and Lube Oil

7.4.25 ST-HL-AE-3266, Special Report Regarding A Diesel Generator Nonvalid Failure on September 19, 1989 (dated 10/19/1989)

7.5 Technical Standards and Manuals

7.5.1 Cooper-Bessemer KSV Standby Diesel Generator Vendor Technical Manual, ETB-DG00-9001

7.6 Drawings

7.6.1 Piping and Instrumentation Drawings

7.6.1.1 5Q159F00045 #1(#2), Sheet 1 (Standby Diesel Generator Fuel Oil Storage & Transfer System)

7.6.1.2 5Q159F00045 #1(#2), Sheet 2 (Standby Diesel Fuel Oil)

7.6.1.3 5R289F05038 #1(#2), Sheet 1 [Essential Cooling Water System Train 1A(2A)]

7.6.1.4 5Q159F22540 #1(#2) (Standby Diesel Jacket Water)

7.6.1.5 5Q159F22541 #1(#2) (Standby Diesel Cooling Water)

7.6.1.6 5Q159F22542 #1(#2) (Standby Diesel Lube Oil)

7.6.1.7 5Q159F22543 #1(#2) (Standby Diesel Air Intake & Exhaust)

0PSP03-DG-0016 Rev. 38 Page 88 of 99



7.6.1.8 5Q159F22544 #1(#2) (Standby Diesel Starting System & Alarms)

7.6.1.9 5Q159F22545 #1(#2) (Standby Diesel Shutdown System)

7.6.1.10 5Q159F22546 #1(#2) (Standby Diesel Starting Air)

7.6.2 Process Flow Diagram

7.6.2.1 5R289F22537 (Essential Cooling Water System)

7.6.3 Electrical Single Line Diagrams

7.6.3.1 0-E-AAAA-01 (Main One Line Diagram Unit No. 1 & 2)

7.6.3.2 9-E-PKAA-01 #1(#2) [4.16KV Class-1E Switchgear E1A(E2A)]

7.6.4 Electrical Elementary Drawings

7.6.4.1 9-E-DG01-01 #1(#2) (Standby Diesel Generators DG11(21), DG12(22), and DG13(23) 4.16 KV Feeder Breakers)

7.6.4.2 9-E-DG02-01 #1(#2) (Standby DG No. 11(21), 12(22), 13(23) Metering)

7.6.4.3 9-E-DG03-01 #1(#2) (Standby DG No. 11(21), 12(22), 13(23) Control, Instrument and Alarms)

7.6.4.4 9-E-DG04-01 #1(#2) (Standby DG No. 11(21), 12(22), and 13(23) Emergency Control and Instrumentation)

7.6.4.5 9-E-DG05-01 #1(#2) (Standby DG 11(21), 12(22), and 13(23) Protection and Control)

7.6.4.6 9-E-DG06-01 #1(#2) (Standby DG 11(21), 12(22), 13(23) Misc Cont)

7.6.5 Interconnection Diagrams

7.6.5.1 0387(01)(02)00030 (Westinghouse Solid State Protection System Interconnection Diagram)

7.6.5.2 0387(01)(02)00035 (Westinghouse Solid State Protection System Interconnection Diagram)

7.6.5.3 0387(01)(02)00228 (Solid State Protection System Actuation Train A Interconnection Diagram)

0PSP03-DG-0016 Rev. 38 Page 89 of 99



7.6.6 Control Schematics

7.6.6.1 4041(8041)-00064(00065) (Starting Sequence Control)

7.6.6.2 4041(8041)-00108(00113) (Instrumentation)






7.6.6.8 4041(8041)-01203(01202) (Engine Governor Control System)

7.6.6.9 4041(8041)-01206(01205) (Miscellaneous)

7.6.6.10 4041(8041)-01207(01206) (Miscellaneous)

7.6.6.11 4041(8041)-01208(01207) (Shutdown and Alarm System)

7.6.6.12 4041(8041)-01209(01208) (Shutdown and Alarm System)

7.6.6.13 4041(8041)-01210(01209) (Legend)

7.6.6.14 4041(8041)-01211(01210) (Terminal Locations)

7.6.6.15 4041(8041)-01212(01211) (Selector Switch Development)

7.6.6.16 4041(8041)-01215(01214) (Generator High Voltage and Regulator)

7.6.6.17 4041(8041)-01216(01215) (Generator Protective Relaying and Metering)

7.6.6.18 4041(8041)-01217(01216) (Generator Voltage Regulator and Tripping)

7.6.6.19 4041(8041)-01218(01217) (Generator Voltage Regulator and Tripping)

7.6.6.20 4041(8041)-01219(01218) (Generator Control Output Interface)

0PSP03-DG-0016 Rev. 38 Page 90 of 99



7.7 STPEGS Procedures and Policies

7.7.1 0PGP03-ZC-0004 (Measuring and Test Equipment Control Program)

7.7.2 0PGP03-ZE-0004 (Plant Surveillance Program)

7.7.3 0PMP08-SP-0001 (RPS/ESF System Normalization)

7.7.4 0POP02-DG-0001 [Emergency Diesel Generator 11(21)]

7.7.5 0POP09-AN-0102 (Annunciator Lampbox 1(2)-102 Response Instructions)

7.7.6 0PSP03-DG-0001 (Standby Diesel 11(21) Operability Test)

7.7.7 0PSP03-DG-0007 (Standby Diesel 11(21) LOOP Test)

7.7.8 0PSP03-DG-0013 (Standby Diesel 11(21) LOOP-ESF Actuation Test)

7.7.9 0PSP03-ZQ-0025 (Diesel Generator Starting Classification)

7.7.10 0PSP03-ZQ-0028 (Operator Logs)

7.7.11 0OOI01-OL-0005 (Operations Logs - Diesel Generator)

7.7.12 0POP02-AE-0002 (Transformer Normal Breaker and Switch Lineup)

7.7.13 0POP04-ZO-0002 (Natural or Destructive Phenomena Guidelines)

7.7.14 0PGP03-ZA-0091 (Configuration Risk Management Program)

7.8 Miscellaneous Items:

7.8.1 CREE 96-16486-1, Evaluate need to revise ESF Diesel start testing due to standby fuel oil pump.

7.8.2 DCP 96-1619-42(45) S2, Replace and upgrade DGFOST 11(21) WR level instruments and remove spared in place NR instruments.

7.8.3 DCP 95-5765-8(11), Standby Diesel Generator Governor Upgrade.

7.8.4 Texas Natural Resource Conservation Commission Federal Operating Permit No. 0-00801 (TNRCC Acct ID# MH-0028-D)

7.8.5 CREE 01-12674-2 (Evaluation of SDG Low Temperature Operability Limit)

7.8.6 CREE 02-5929-1 (SDG Operability without Standby Lube Oil or Standby Jacket Water Pumps)

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7.8.7 DCP-04-11502-8 ESF Transformer E2A (7E132EAT0E1A) and 4.16KV/480 V Load Center Transformers E2A1 and E2A2 Tap Setting Changes

7.8.8 CREE 11-10521-1 Provide guidance to reduce Loaded Operating Voltage ranges for ESF Diesels to prevent exceeding 480 V Load Center maximum voltage.

7.8.9 CR 06-6049-4, Industry Practices for DG Operability When Parallel With Grid

7.8.10 DCP 98-175-1, Addition of CREE 07-13247-1 Information to DG VTD

7.8.11 CR 04-11112, Provide Procedure Change Recommendations Regarding Jacket Water Standpipe Level to Operations Support.

7.8.12 CR 07-8590, Determine/Evaluate the Proper SBDG JW Standpipe Level for Standby and Post-Run Conditions

7.8.13 CREE 11-10521-11, Provide ESF Bus Voltage Range to Allow Sufficient Margin for Standby Diesel Generator Loading During Surveillance Testing

7.8.14 CREE 11-10205-19, Provides Class 1E 480 Volt LC Bus Operating Upper Voltage Limit (507 Volts)

7.8.15 ST-HL-AE-2489, Special Report Regarding Two Diesel Generator Nonvalid Failures (dated 01/28/1988)

7.8.16 CR 10-11100, Actions 24, 25 and 26 – Delete the requirement for a Unit Supervisor or Shift Manager to be present at the Control Panel during synchronization of the Diesel Generator (removed commitment previously incorporated by ST-HL-AE-2489 dated 01/28/1988)

7.8.17 CREE 11-12398-1, During performance of procedure 0PSP03-DG-0016, “Standby Diesel 11(21) Twenty-Four Hour Load Test”, the UAT Load Tap Changer (LTC) was adjusted to 3L in order to obtain the required KVAR and voltage requirements as specified in the procedure. Procedure 0POP02-AE-0002, “Transformer Normal Breaker and Switch Lineup” states the UAT LTC lower setpoint is 5L to avoid a degraded bus voltage condition.

7.8.18 CREE 11-17472-59, Determine how to conduct SDG surveillance testing while keeping the LTCs in Auto.

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8.0 Support Documents

8.1 Addendum 1, DG 11(21) Recorder Installation/Removal

8.2 Addendum 2, Technical Specification Surveillance Requirements Satisfied Table


0PSP03-DG-0016 Rev. 38 Page 93 of 99 Standby Diesel 11(21) Twenty-Four Hour Load Test

Addendum 1 DG 11(21) Recorder Installation/Removal Page 1 of 6

Yokogawa Recorder User Guide for 0PSP03-Diesel Run:

NOTE

Technical Specification Surveillance Requirement 4.8.1.1.2.a.2 specifies the following:

• “Verifying the diesel starts from standby condition and accelerates to 600 rpm (nominal) in less than or equal to 10 seconds. The generator voltage and frequency shall be 4160 + 416 volts (3744 to 4576) and 60 + 1.2 Hz (58.8 to 61.2) within 10 seconds after the start signal.”

• The requirement to verify the diesel “accelerates to 600 rpm (nominal) in less than or equal to 10 seconds” is satisfied by verifying the diesel generator frequency is 58.8 to 61.2 Hz within 10 seconds of the diesel start signal. Diesel generator frequency is directly related to diesel generator rpm (i.e., 60 Hz is directly proportional to 600 rpm.)

A. Load SETUP file (completion of Steps A1 thru A12 enables recorder to capture surveillance data)

1. Press “FILE” button on lower right of recorder. _____

2. Press soft key “FILE ITEM” and select “SETUP”. _____

3. Press “LOAD” soft key. _____

4. Using rotary dial, highlight desired path:

a. “HD0” for hard drive OR “USB” for flash drive, _____

b. and then press “SELECT” button. _____

5. Using rotary dial highlight file “0PSP03-DGRUN.SET”. _____

6. Press “LOAD EXEC” soft key twice to load file. _____

7. Press “ESC” button three times to clear screen and display CH1 – CH4 pop-up window _____

8. Press “START” button. _____

9. Press ‘PROTECT” button, Verify red LED is ON. _____

10. Verify “waiting for trigger” display flashing at lower left of screen after one minute. _____

11. Verify channels 1, 2, and 4 are tracking at ~ 1.00 VDC. _____

12. Verify channel 3 indicates ~ 0.0 VDC. _____




The recorder is now set to trigger and capture surveillance data on a start signal. After data collection is complete, and the diesel is in a suitable condition, perform the following steps to analyze data. Voltage: 4160 + 416 recorded as M1 on CH1, (X1 value < 10 seconds) (Min. Y1 value 3744 VAC = 3.853 vdc) (Max.Y1 value 4576 VAC = 4.486 vdc) Frequency: 60 + 1.2 Hz recorded as M2 on CH2, (X2 value < 10 seconds) (Min. Y2 value 58.8 Hz = 2.520 vdc) (Max. Y2 value 61.2 Hz = 3.480 vdc) Start signal: 125 vdc recorded as M3 on CH3, (X value = 0.000 seconds) (No min/max, used to trigger recorder @ 40vdc increasing and as t0 reference) B. Set MARKERS (The start signal, CH3 trigger, is the time reference for the other values.)

1. Press “PROTECT” button on recorder bottom left, verify red LED is OFF. _____ 2. Press “FILE” button, Press soft key “FILE ITEM”, select “WAVEFORM”. _____ 3. Press “CURSOR” button, Press soft key “CURSOR TYPE”, Select “MARKER”. _____ 4. Press soft key “SELECT” to scroll to “M1”. _____ 5. Press soft key “TRACE”. _____ 6. Scroll rotary dial to highlight “CH1” then press “SELECT” button. _____ 7. Repeat steps 4. thru 6. (M2 to CH2) and (M3 to CH3) _____

C. Set ZOOM Feature (This provides sufficient resolution to obtain data.)

1. Press “ZOOM” button. _____ 2. Press soft key “MODE”, Select soft key ”MAIN & Z1”. _____ 3. Press soft key “Z1 MAG”, Scroll rotary dial to set “1MIN”. _____ 4. Press soft key “Z1 Position”. _____ 5. Scroll rotary dial to bracket start signal and signal ramps within zoom window. _____

D. Set CURSOR Feature (This marks, compares, and computes required data.)

1. Press “CURSOR” button on lower recorder. _____ 2. Scroll soft key “SELECT” to highlight “M3”. _____ 3. Use rotary dial to position M3 cursor (+) at point on CH3 start signal trace where X3 = 0.00 seconds. _____ 4. To adjust rotary dial sensitivity press “POSITION” soft key and select desired

decimal increment by pressing < > buttons under rotary dial, repeat as required. _____ 5. Scroll “SELECT” soft key to highlight “M2”. _____ 6. Use rotary dial to position M2 cursor (+) Y2 at 2.520 on CH2 frequency trace. _____ 7. Scroll “SELECT” soft key to highlight “M1”. _____ 8. Use rotary dial to position M1 cursor (+) to the point on CH1 voltage trace where

X1(CH1) time value is equal to X2(CH2) time value. _____ 9. Press “PRINT” button. _____




Recorder Installation Instructions

NOTE


• WHEN the recorder is being connected to the DG, THEN the recorder should be unplugged (SPR 933560)

• Double fused leads SHALL be used for the START and engine SPEED signals on the recorder.

• “65GSC” is “701 Digital Speed Control”.

• Pre-test and post-test calibration is NOT required for Yokogawa recorder.

ENGINE CONTROLPANEL

(ZLP102)

125 VDC

DIESEL GENERATORVOLTAGE/FREQUENCY TRANSDUCER INTERFACE

250

Ohm

887

654321

8

654321

STARTCHANNEL0-100 VDC

FREQUENCYCHANNEL1-5 VDC

(55-65 Hz)

VOLTAGECHANNEL1-5 VDC

(0-5250 VAC)

SPEEDCHANNEL1-5 VDC

(0-700 RPM)

RECORDERRECORDER

250 Ohm

ENGINE CONTROL PANEL(ZLP102)

GENERATORCONTROL

PANEL(ZLP101)

120 VAC

120 VAC738739

FREQUENCYTRANSDUCER

VOLTAGETRANSDUCER

50+58-

1

654321

6

5

12111098765432

65GSC701 DIGITAL SPEED

CONTROL




Recorder Setup

Record the Channel used for each signal listed below:

Signal Channel Initials

DG VOLTAGE Channel DG FREQUENCY Channel DG START Channel DG SPEED Channel SPARE Channel SPARE Channel SPARE Channel

A. Scale the DG VOLTAGE Channel and FREQUENCY Channel for 0 - 5 VDC full scale. Use the full recorder paper width for both traces to improve data resolution. Crossing of the traces on the paper is acceptable, however overlap should be avoided. _____

B. Scale START Channel to indicate the presence of the 125 VDC signal at engine start. _____

C. Scale SPEED Channel to indicate engine speed. _____

D. On monitoring engine starts, set the recorder speed at 100 mm/sec. Other recorder speed traces may be set at 10 mm/sec. _____

E. Indicate on the y-axis of the graph the scaling for the DG VOLTAGE Channel and FREQUENCY Channel. _____




Recorder Setup

Recommend using a GRAPHTEC Model WR 7700 recorder setup as indicated below:

VOLTAGE CHANNEL 1-5 VDC 0-5250 VACFREQUENCY CHANNEL 1-5 VDC 55-65 HzSPEED CHANNEL 1-5 VDC 0-700 RPMSTART CHANNEL 0-125 VDC

Enable Time : 16:06:41Disable Time : 16:07:22Trigger Time : 16:06:42Time Scale : 20.0msec/cm (Memory Y-T mode)Chart Speed : 100mm/sec (Direct Y-T mode)Scaling Factor : 1 (Memory Y-T mode)

Block 8K-1

Size 100%

Delay : +000%Action : Single< Memory >

Source

Manual--

-- ----

---- --

CH. Level Slope

Combination

< Trigger >

AMPSVoltageChannel

FrequencyChannelSpeed

ChannelStart

ChannelChannels

NOT USED

Input

DC

DC

DC

DC

OFF

Range

5V

5V

5V

100V

0.1V

Voltage Ch 1-5 vdc 0-5250V

Annotation

Freq Ch 1-5 vdc 55-65Hz

Speed Ch 1-5 vdc 0-700PRM

Start Ch 1-125 vdc

Filter

5Hz

5Hz

5Hz

5Hz

OFF

Vern

FIX

FIX

FIX

FIX

FIX

< DATE > 93/08/18< TIME > 16:07:22Mode = Direct Y - TFormat 160mmX1Axis X: - Y: -Sampling = 200usec

Volt Ch5V

Freq Ch5V

Speed Ch5V

Start Ch100V

Channel ModulesVERNI switchesSHALL be set to OFF




NOTE

The output voltage of the voltage and frequency transducers is 1 - 5 VDC for 0 - 5250 VAC and 55.0 - 65.0 Hz, respectively. As a result, the effective recorder range is 20 - 100% for the DG VOLTAGE Channel and FREQUENCY Channel.

Pre-Test and Post-Test Recorder Calibration Guidelines

Using the DMM to measure voltage, input the following voltages to the DG VOLTAGE Channel and FREQUENCY Channel. Briefly operate the recorder at each plateau. Record the “Equivalent Voltage” and “Equivalent Frequency” on the recorder traces. _____

VOLTAGE Channel FREQUENCY Channel Input Voltage Equivalent Voltage Input Voltage Equivalent Frequency 1.000 VDC 0 VAC 1.000 VDC 55.0 Hz 3.853 VDC 3744 VAC 2.520 VDC 58.8 Hz 4.170 VDC 4160 VAC 3.000 VDC 60.0 Hz 4.486 VDC 4576 VAC 3.480 VDC 61.2 Hz 5.000 VDC 5250 VAC 5.000 VDC 65.0 Hz


0PSP03-DG-0016 Rev. 38 Page 99 of 99


Addendum 2 Technical Specification Surveillance Requirements Satisfied Table

Page 1 of 1

Technical Specification Satisfied Procedural Steps Performed

4.8.1.1.2.a.1 5.14 (1)

4.8.1.1.2.a.2 4.8.1.1.2.a.4 4.8.1.1.2.e.5 4.3.2.2.2.a.9(2) 4.3.2.2.3.a.9(2) 4.3.2.2.5.a.9(2)

5.3, 5.12, 5.14 (1)

4.8.1.1.2.a.3 5.7

4.8.1.1.2.b 5.13, 5.14 (1)

4.3.2.1.1.a.42) 4.3.2.1.1.c.72) 4.8.1.1.2.e.3

5.3, 5.6, 5.10, 5.14 (1)

4.8.1.1.2.e.7 5.7, 5.8, 5.14 (1)

4.8.1.1.2.e.10 5.4

(1) Step 5.14 (appropriate sections) (2) PARTIAL Technical Specification completion

IEEE Std 387-2017 Technical Basis Matrix (Master) Revision...

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