ML18228A481

04/04/1978 Letter Response to Request for Additional Information on System Disturbance of May 16, 1977

ML18228A481
Person / Time
Site:	Turkey Point
Issue date:	04/04/1978
From:	Robert E. Uhrig Florida Power & Light Co
To:	Schwencer A Office of Nuclear Reactor Regulation
References
Download: ML18228A481 (74)

Text

DISTRIBUTION &TER ISSUANCE OF PERATING LICENSE iVRC Fcf~~ 195 U.S. NUCI EAA REGVI ATORV Cob'ION QQC ER (2-7S) - o- 2s- 2w/ 35 NRC DISTRIBUTION FoR PART 50 DOCKET MATERIAL FROM: GATE OF OOCUMENT Mr. A Schwencer FPL 04 04 Miami, FL 33101 OATE AECEIVFQ 04/06/78 BL ETTER QNQTOAI2EQ PROP INPUT FORM NUMBEA OF COPIES RECEIVEQ

~OA I G INAI. PCl4C I.ASSI F I E Q QCOPV sr@>eG Response to NRC ltr dtd 03/16/78 ~ ~ ~

OESCRIPTION ENCI.OSU RE Furnishing addi info re the FPL system distrubance which occurred on May 16~ 1977 ' ~

w/ a't t o ~ ~

1p 1/4li PLANT NAME. TURKEY POINT UNITS 3 & 4 Z~~ g~pRO MOIi 4'5 ST LUCIE UNIT 1 Q Q.lad &5 jcm 04/08/78 SAFETY FOR ACTION/INFORMATION LL OrffE,e. SSQCil/

BRANCH CHIEF: 7 -wCL ~

EG I'NTERNAL 0 Rl BUTION C I NC 0'C EXTERNAL OISTRIBUTION CONTROL NUMBER SIC 780970001 CRS 1 CYS SENT CATE

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.O. BOX 013100, MIAMI, FL 33101 MIUIliidi; FLORIDA POWER 8( LIGHT COMPANY April 4, 1978 L-78-118 Office of Nuclear Reactor Regulation Attention: Mr. A. Schwencer, Chief C9 C/ ~

Operating Reactors Branch Nl ~, 1 Division of Operating Reactors U. S. Nuclear Regulatory Commission CXI Washington, D. C. 20555 PcD

>>4 g) g rclCPM

Dear Mr. Schwencer:

(

Re: Florida Power I('ight Company (FPL) CA Docket Nos. 50-250, 50-251, and 50-335 Re uest for Additional Information Your letter of March 16, 1978 requested additional infor-mation regarding the FPL system distrubance which occurred on May 16, 1977- Our responses to your additional questions are attached.

Very ly yours, Robert E. Uhrig Vice President REU/MAS/mb Attachment cc: Mr. James P. O'Reilly, Region II Harold F. Reis, Esquire PEOPLE... SERVING PEOPLE

ATTACHMENT Re:. Florida Power & Light Company (FPL)

Docket Nos.,50-250, 50-251, and 50-335 Re uest for Additional Information QUESTION 1 The response to request 1.3 gives limitations on the line based on long-term operation. Please provide any opera-tional guidance that may exist'uch as "The line may be operated at above x amperes but not. exceeding y amperes for a time not to exceed z minutes," where z is a number small enough to provide operational guidance.

Line sag is computed for two different temperatures, but no indication is given as to what the temperature of the line was when't relayed open. Please provide any recorded data on the line current over this 16-minute period (10:08-10:24) from which a temperature profile could be deter-mined.

RESPONSE 1 There is no guide for overloading conductors in the form of X < Y for 2 minutes.

There is no recording of the load on the Fort Myers-Ranch lines. The loading was computed from other charts. The sag figures were included to show that even under extreme conditions of ambient temperature and light wind that, it is highly improbable that the conductor would have sagged enough to contact some object to cause the phase to ground fault.

,I Page 2 Re: Florida Power 6 Light Company (FPL)

Docket Nos. 50-250, 50-251, and 50-335 Re uest for Additional Information QUESTION 2 The power estimates given in response to request 1.6 are not supported by the'ata on which they were based. Please provide the 16-minute (10:08-10:24) record of each variable that was used in making this power calculation and a sample of how the calculation was made.

A reference is made in this response to past histroy of division of the load (between the two Ft. Myers-Ranch lines).

Please provide any records of such a division of transmis-sion on these lines at approximately 500-600 MW total power.

In a dynamic situation such as the system was then exper-iencing would the relative loading of the two li'nes be expected to oscillate so that an average relative loading would not reflect peak conditions on one? If so please discuss the details.

In the response to 1.6, oscillogram records from Ringling are included; oscillogram records from Broward and Midway are cited but not included. Please, furnish copies of the Broward and Midway oscillogram reco'rds.

Since oscillogram records at locations remote from'a fault cannot be interpreted without some knowledge of the inter-vening circuitry, particularly transformer coupling, please furnish the indicated intervening circuitry description for Ringling, Broward, and Midway.

RESPONSE 2

'The line flows from Fort Myers to Ranch were computed 'as follows:

a) Power available to the Western Division is the sum of the output of the plants in the Western Division minus the tie flows to Tampa Electric Company (flows into Florida Power &

Light are negative numbers). These values are obtained from the various strip charts for the time period under consideration. (Charts were previously transmitted.) An additional chart "Area Loads" is attached to verify the

'before'oad. (Appendix C) b) Load in. the Western Division: Load prior to the disturbance is obtained from the strip chart showing the area loads.

.'fter the initial disturbance, the area load chart, showed

C> 0 Page Re: Florida Power & -Light Company (FPL)

Docket Nos. 50-250, 50-251, and 50-335 Re uest for Additional Information a load in the Western Division which, if true, would have indicated a reduction in line flows from Ft, Myers to Ranch.

The known deficit of generation in the south, the observation by plant personnel at Fort Myers and the alarm signal from the West Palm computer, all indicate'that the power flows from Fort Myers to Ranch did indeed increase. There was no interruption of feeders in the Western Division but during this period the area substation load would increase; any other change in area load is due to .a change in the trans-mission line losses in the Western Division. An estimate of'he total load in the Western Division was made.

c) The total power flow from Fort Myers to Ranch is the power available to the Western Division ( a) above) minus the load in the Western Division ( b) above).

d) 'The division of power flow on the Fort Myers-Ranch 240kV line and on the Fort Myers-Ranch 138kV line, for analysis purposes, may be treated in two steps-.. (1) The division of power flow to satisfy the load requirement of the sub-,

stations served between Fort Myers and Ranch (all such substations are connected to the 138kV line). This total power flow equals the sum of the load at the served sub-,

stations. (2) The division of all other power flow in excess of (1). Both of these divisions must obey Kirchhoff's laws and can be combined using the superposition theorem to

, give an estimate of the individual line flows. As the total flow from- Fort Myers to Ranch increases, the division will more nearly be that, of (2). Using a D. C. analog calculating board set up to represent the reactances of the transmission lines and transformers, the (2) division was determined to be .

75% on the Fort Myers-Ranch 240kV line and 25% on the Fort, Myers-Ranch 138kV line.

The attached- table (Appendix C) shows the values of the Fort Myers-Ranch 240kV line flows for significant times during the disturbance on Florida Power 6 Light Company's system of May 16, 1977.

There are no records showing the division of load on these two lines at approximately 500 600 MW total power.

In a dynamic situation, the relative loading of the two Fort Myers-Ranch lines would be expected to vary together according to Kirch-hoff's laws with no oscillation between the two circuits.

Page 4

~

, Re: Florida Power 6 Light Company (FPL) .

Docket Nos. 50-250,.50-251, and 50-335

. Re uest for Additional Information The,oscillograms for Broward and Midway are attached (Appendix C).

Please note that all traces on the Broward oscillogram are from the 138kV side of the station. The 138kV and 240 kV sections are connected through Wye connected autotransformers, solidly grounded.

A diagram- of the transmission system is attached (Appendix C).

Generator transformers have been omitted to reduce clutter. All generators are connected to the system through delta wye trans-formers. The high side is wye, solidly grounded. A schematic drawing is also included.

Page 5 Re: Florida Power 6 Light Company (FPL)

Docket Nos. 50-250, 50-251, and 50-335 Re uest for Additional Information QUESTION 3 The response to request 2 "We have concluded that, the Turkey Point trip could not by itself, have caused the line to relay" is not supported. Please furnish any supporting analyses with a full description.

RESPONSE 3 The conclusion that the system was stable at 10:24 a.m., May 16, 1977, was based on the following:

1) The system continued to operate for 16 minutes follow-ing the loss of Turkey Point No. 3.

2) Oscillograms from Ringling show no sign of instability before loss of Fort Myers-Ranch circuit.

3) Oscillograms from Midway show no sign of instability before the loss. of Fort Myers-Ranch circuit.

4) Oscillograms from Broward show no sign of instability before the loss of the Fort Myers-Ranch circuit.

5) Total generation was increasing. Copy of total genera-tion chart attached (Appendix D).

6) There were no reports from operators that voltage, watts or vars were oscillating.

7) The Fort Myers-Ringling 240kV circuit tripped at both ends. Since the relays are directional, only one end would overload condition. Only an internal trip for an 'infeed fault could cause from both ends. There were=

ground targets at Ranch and at Fort Myers. Circuits tripping from an unstable condition will trip with phase targets. Since all three phases must swing together, the swing is balanced and therefore there is no ground current to operate ground relays.

8) From ratings furnished by conductor manufacturers, we have obtained conductor temperatures for various con-ditions of loading and ambient temperature. From the

Page 6 Re: Florida Power a Light Company (FPL)

Docket Nos. 50-250, 50-251, and 50-335 Re uest for Additional Xnformation SCADA alarm 'log from Nest Palm Beach, we can determine that the watt loading was near or slightly above the alarm'setpoint of 418MW, and that the VAR loading was below the setpoint of 147MVAR. This loading is such that it is highly unlikely that the conductor would sag enough to contact some object and cause a phase-to-ground fault. The loadings are reasonably confirmed by taking the change in ties, change in-generation, and change in'west coast load to determine the total power flow at the time of loss.

9) The line loading of the Fort Myers-Ranch line was well under the tripping value.

Setting sheets are attached (Appendix D) with a plot of the. relay characteristic in terms of R & X and a plot in terms, of watts and vars.'

Page 7 Re: Florida Power 6 Light Company (FPL)

Docket Nos. 50-250, 50-251, and 50-335 Re uest for Additional Information QUESTION 4 The response to request 3 appears to suggest that the cal-culation involving the loss of Turkey Point 4 in the FCG study is to be considered to bound the events which occurred around 10:08 on 5/16/77. If this suggestion is intended, please furnish a detailed description of this calculation showing relevant detail which causes bounding.

it to be regarded as RESPONSE 4 The Stone & Webster report to the Public Service Commission dated May 10, 1973, recommended system studies relating to items such as load shedding and line relaying. Stone Webster was retained to perform such studies and prepare recommendations. From these, modifications in operating and design practices have been implemented.

An additional stability study, performed by an FCG task force, involved an off-peak load level case study of the loss of one Turkey Point unit with the cross-state 500 kV line out of service. In response to your request for a detailed description of this "calculation", those por-tions of the FCG study that relate to this specific case are attached as Appendix A.

The computer program used is the PECO stability program which was run on the Florida Power Corporation IBM 370/168 system at St. Petersburg, Florida. The study is considered reasonable as a bounding case for the first event of May 16, 1977. The study case assumes the 500 kV cross-state line out for maintenance, assumes an FPL load level of 4634 MW, and assumes the loss of a large unit at Turkey Point (700 MW). On May 16, the 500 kV line was out, the FPL load at 10:07 a.m. was 4710 MW (net), and the unit dropped at Turkey Point was carrying 684 MW (net). The study case indicated that such a syst: em was stable. In fact, on load May loss, 16, the system remained stable (e.g., no cascading no line relay action, frequency decay arrested and returned to normal) following the disturbance at 10:08 a.m. involving the trip of the Turkey Point unit.

You may also wish to refer to the Federal Power Commission report for the first quarter of 1977 (partial copy attached as Appendix B)-

Page 8 Re: Florida Power & Light Company (FPL)

Docket Nos. 50-250, 50-251, and 50-335 Re uest- for Additional Information QUESTION 5 The response to request 6 is not clear in some respects.-

Is our understanding that Southern Co. and Florida Power and Light Company have not yet entered an agreement for .a

,500 kV Georgia-Florida tie correct? Is our understanding that 800 MN interchange capability from Georgia to Florida (which was, according to referenced FPGL reports, to be ready in 1976) is not yet available correct?

RESPONSE 5 The load growth and the generation/transmission expansion plans of both Florida and Georgia were revised to reflect the slower economic growth of the nation. The need for additional transmission tie 1ines between Florida and Georgia was altered accordingly. Thus, the in-service date for the 500 kV tie is now conceived by both Florida and Georgia to fall into the late 1980's (possibly as late as 1990). Therefore, no agreement with Georgia has been reached.

This will be monitored closely by the Federal Energy Re-gulatory Commission, SERC, FCG, Florida Public Service Commission, Georgia Power Company, and Flo'rida Power 6 Light Company.

A January 1980 in-service date for a 240 kV line from Yulee (Florida) to Kingsland (Georgia) has been agreed to by Georgia Power Company and Florida Power 6 Light Company with additional supportive facilities to establish a transmission interconnection.

Page 9 Re: Florida Power S'ight Company (FPL)

Docket Nos. 50-250, 50-251, and 50-335 Re uest for Additional Information QUESTION 6 The reply to request 7.3 is not fully responsive. Please provide the discussion requested.

RESPONSE 6 Turkey Point, Unit 4 was removed from service to perform scheduled refueling, maintenance, and inspections of nuclear and non-nuclear systems on May 9, 1977. Maintenance and refueling are occurrences which are normal and anticipated.

Generating capacity available was sufficient to meet anticipa-ted loads with adequate reserve margins. Because periodic maintenance of generating facilities is a routine procedure, and had begun seven days prior to the disturbance on May 16, there was no need for a specific discussion of this event within the referenced report. A status of all installed capacity at 10:08 a.m., May 16, 1977, was included in the report as Figure 5.

The Andytown-Orange River 500 kV line had been operating at 230 kV since 1974. Conversion to 500 kV was scheduled for 1977 and construction had begun in 1976 to accomplish this.

On May 9, 1977, the line was removed from service on a continuous clearance for final line work. The line was temporarily energized at 500 kV on May 14. On Sunday night, May 15, the line was removed from service in accordance with a clearance scheduled on May 16; to permit final calibration of protective systems.

Removal of transmission facilities from service from time to time to facilitate construction or maintenance is a normal practice. For these reasons it was not necessary to discuss this within the referenced report. The status of the Andytown-Orange River 500 kV line on May 16, 1977, is clearly indicated on 'Figures 2 and 4.

The "Report on System Disturbance, May 16, 1977" was prepared to address the disturbance and provide an analysis of those events directly related to it. The Report and Exhibits taken initial condition of:the as a whole, clearly establish the system on May 17, 1977. A discussion of events, prior to that time, was not intended since the system was operating within limits on the morning of May 16.

APPENDIX A

APPENDIX A FLORIDA ELECTRIC POWER COORDI~ING GROUP (FCG) 402 REO NCREET, SUITE 214 ~ TAMPA, FLORI~33609 ~ (813) 877.5301 July 27, 1977 SYSTEM PLANNING COMMITTEE:

Mr. J. S. Bell, Florida Power 6 Light Company Mr. R. T. Bowles, Florida Power Corporation Mr. Larry Gawlik,,Gainesville/Alachua County Regional Utilities Board Mr. M. W. Howell, Gulf'ower Company Mr. R. T. Dyer, Jacksonville Electric Authority Mr. R. E. Arnold, Lake North Utilities Authority Mr. R. W. Cochran, Lakeland Department of Electric Water Utilities Mr. D. E. Moore, Orlando Utilities Commission Mr. R. W. Claussen, Seminole Electric Cooperative, Inc.

Nr. G. T.'Lawrence, City of Tallahassee Electric Department Mr. R. E. Proctor, Tampa Electric Company

SUBJECT:

OFF-PEAK TRANSIENT STABILITY STUDY FOR 1977 The 1977 Transient Stability Task Force was assigned to investigate the transient response of the State Bulk Power System for various contingencies which may occur during off-peak operating conditions. These contingencies are set forth in SERC Guidelines, Number 3, "Criteria for Reliability in System Planning." The recommendations of this study will assure that cascading outages will not result from any foreseeable contingencies.

This study was the combined effort of individuals in every member company of the System Planning Committee.

During the months of January and February, the Task Force spent two weeks in St. Petersburg, Florida, in order to expedite this study.

Respectfully submitted, 1977 Transient Stability Task Force:

G. L. Hofacker, Chairman (FPL)

A. N. Darlington (TEC)

G. F. Erickson (OUC)

C. N. Hansen,(FPC)

H. D. Powell (JEA)

GLH/ds

INTRODUCTION The System Planning Committee commissioned the 1977 Off Peak Transient Stab@la,ty Task Force to analyze certain transient stability phenomena of the Interconnected Generation/

Transmission System proposed to be in service during l977.

System planning person'nel from the following utilities either worked on the Task Force or provided data to produce the results stated in this report:

Florida Power Corporation Florida Power 6 Light Company Gainesville-Alachua County Regional Utilities Board Jacksonville Electric Authority.

Utiliities h

Lakeland Department of Electric & Water Orlando Utilities Commission City of Tallahassee Tampa Electric Company The general study categories are listed below:

l. Generation Losses

, A three-part analysis associated with:

a. 'he transient effects associated with single nuclear generator contingency outages.

b. The transient effects associated with multiple generator contingency outages.

c ~ The transient effects associated with single nuclear generator contingency outages on a fragmented transmission system.

A-2

2. Transmission Losses An analysis of the transient effects on the, system resulting from a three-phase, delayed-clearing fault.

These studies were run on Florida Power Corporation's IBM System 370 Computer, utilizing the Philadelphia Electric Company (PECO) Load Flow and Transient Stability programs--

the latter modified by Florida Power Corporation.

The Task Force met during the last week of January 1977 and, the last two days of February 1977 in St. Petersburg,

,Florida, to run and analyze cases. All case studies were completed on the computer by the end of April 1977.

The features incorporated in the modified version of the Transient Stability program include:

1. Provision to model underfrequency relays allowing three independent set points and intentional relay time delay settings at each bus with separate and independent breaker time.

2. Provision to model most transmission line relays which may operate due to positive sequence transients.

3- Relay representations included the following types:

a. Impedance

b. Reactance

c. Underfrequency

d. Directional Comparison Carrier Blocking

'Each distance relay could be modeled with three separate distance and time settings and independent breaker trip and reclose time specification.

A-3

4. .Summary Reports for:

a. Load damping for selected areas.

b." Turbine response for selected areas.

c.. Line flow change for selected lines.

d. Line flow for selected lines.

e. Machine frequency and angle for all units.

A-4

PURPOSE The purpose of these studies was to analyze the 1977 State system to provide an understanding of the transient response during off-peak conditions. The primary interests were to:

Simulate selected single unit generation outages under two circumstances; with complete trans-mission system and fragmented transmission system.

2. Determine if emergency reactor coolant pump operation would be initiated on nuclear generating units.

3- Determine the underfreguency relay response in the State for the 1977 time period such that no

~ firm load would be shed for the loss of the largest unit.

4 ~ Determine if the response of the Florida bulk power system to the'contingencies studied would result in any cascading from the Peninsular Florida Subregion into the Southern Company Subregion.

Provide a,report to be used as a guide for future

'I studies on the subject.

, A-5

PERIOD OF STUDY This study was done considering certain significant generation and transmission facilities to be in service.

These facilities were (1) the Andytown Orange River 500 kV line, and (2) Crystal River Unit 3, St. Lucie Unit 1, and Port Manatee Unit l.

The task force used the published Florida Load Duration Curves for 1974 to determine the value for the off-peak load level. The load value was plotted as a function of the duration of that particular load level during the year 1974.

The peak of this curve was selected as a starting point and the duration of each load point above and below the center point was summed to determine the percent load range that represented 50 percent of the time. The recommended load level is that load level which falls mid-way in this range.

This value compares very closely with the composite load duration curves published in the subject report. The load vel chosen was 5 ercent of the 1977 estimate of summer o d of eac utilit . Adjustments to this figure were made by Florida Power Corporation and Tampa Electric Company, reflecting industrial load. It was assumed that. a high power factor would be in effect at this load level; hence, no transmission compensation was required.

A-6

The load. level and spinning reserve used in the Base Case Load Flow is tabulated below:

Load and Spinning Losses Reserve Utilit (MN) (m)

Florida Power Corporation (FPC) 2,417 340 Florida Power & Light Company (FPL) 4,634 486 Gainesville-Alachua County RUB (GVL) 101 21 Jacksonville Electric Authority (JEA) 709 181 City of Lakeland (LAK) 131 37 Orlando Utilities Commission (OUC) 259 101 City of Tallahassee, (TAL) 139 . 68 Tampa Electric Company (TEC) 1,125 207 State of Florida Total 9,515 1,441 Southern Company Equivalent 11,414 0 TOTAL 20,929 1,441 A-7

CASE TSS-77-4A2 LOSS OF TURKEY POINT UNIT 4 (700 MW)

WITH FRAGMENTED TRANSMISSION SYSTEM This case simulation was chosen in order to observe the transient response of the system for the loss of a large generating unit in extreme southern Florida during a time period when certain transmission circuits considered vital to maintain system integrity have been removed. This condition is analogous'to having these circuits removed for maintenance.

The transmission lines selected for removal were the Andytown Orange River 500 kV circuit, the Midway Indiantown 230 kV circuit; and the Central Florida Clermont East 230 kV circuit.

Specific items of interest are:

1) The transient response of the state for the loss of a significant percentage of dispatched system generation during off-peak conditions.

2) The resulting frequency and voltage response which may cause the operation of emergency reactor coolant pumps.

if underfrequency

'I

3) To determine load shedding

,will occur.

4) To observe any tendency toward cascading.

A-8

RESULTS AND OBSERVATIONS The loss of this unit resulted in the frequency'decline of the other units in the state. Turkey Point Unit 3 reached a minimum frequency of 59.58 Hz at approximately T = 0.35 second.

This frequency represented the lowest that occurred on any State of Florida generating unit. Frequency deviations from 60.00 Hz on those units'progressively removed from Turkey Point were smaller and occurred later in simulation time (see Figure 4A2-2).

System response recovered the 700 MW loss by T = 0.7 second.

The largest initial -contribution was from load damping, followed respectively by tie line flows and turbine response (see Figure 4A2-1). The load damping peak was 697 MW at T = 1.7 seconds; turbine response peaked 0.1 second later at 243 MW.

Tie lines were exporting approximately 3 MW of power when the unit outage occurred (see Figure 4A2-3). These tie lines were composed of the following circuits:

1) Suwannee-Archer 230 kV

2) Ft. White-Xnglis 115 kV

3) Ft. White-Newberry 115 kV

4) ,Ft. White-High Springs 69 kV Net power flow over these tie lines reversed at T = 0.2 second, increasing to a peak of 515 MW at. T = 2.4 seconds to the south. No transmission line relays operated dur'ing the course of the study.

A-9

A voltage profile for selected buses throughout the state reveals the following excursions from initial conditions:

TABLE I: VOLTAGE PROFILE (PERCENT)

Initial Minimum Voltage Bus Vo~tacae Voltage Difference 8 T=4.0 Turkey Point 230 kv (FPL) 105. 7 96. 5 -9.2 104. 9 Andytown 230 kv (FPL) 105.1 92. 2 -12.9 102. 6 Ft. Myers 230 kv (FPL) 104.9 92. 2 -12.7 101.7 .

Midway 230'v (FPL) 105.6 94. 6 -11.0 101. 8 Volusia 230 kv (FPL) 104.4 100. 6 -3.8 103. 7 Suwannee 230 kv (FPC) .'02. 3 94. 6 7e7 103. 5 Crystal River 230 kv (FPC) 105. 7 101. 3 -4 4 106.1 Gannon 230 kV (TEC), 104. 7 101. 7 -3. 0 103. 8 Pebbledale 230 kv (TEC) 101.8 97. 9 -3. 9 100.4 Northside Indian River 230 kv (JEA) 101. 7 100. 3 -l. 4 101.3 230 kv (OUC) 105.7 101. 1 -4. 6 105.0 Larsen 69 kv (LAK) 102.7 98. 2 -4 .5 100.2 Hopkins 230 kv (TAL) 100.7 98. 3 -2. 4 101.7 Parker Road 230 kv (GVL) 103.7 94.7 -9. 0 103.1

/

t The, lowest free(uency and terminal voltage occurring on the three remaining nuclear generating units are tabulated below:

TABLE II: NUCLEAR GENERATING UNIT DATA Lowest Lowest Terminal Frequency Voltage Unit (Hz) (Percent)

Turkey Point 3 59. 58 92.4 St.'Lucie 1 59.77'9.80 89.8 Crystal River 3 100.1 A-10

CONCLUSIONS Based on the assumptions included in this study, the following conclusions can be stated:

1) There will be no separation of Peninsular Florida from the north for the loss of this unit.

2) The resulting frequency and voltage response of the three nuclear units connected to the system is such that emergency reactor coolant pump operation will not be initiated.

3) No load shedding will occur.

4) No transmission line relay operations will occur from the loss of this unit.

5) No tendency toward cascading was observed.

1400 SYSTEM RESPONSE LOSS OF TURKEY POINT 4

{700MN)

FRAGMENTED TRANSMISSION SYSTEM 1200 TSS-77-4A2 Total Response Line Flow Change -

Gross Load Damping-Turbine Response

~ ~ ~

1000 8 800 X

I

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m 600

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C R

~ ~

400 ~ ~

~ ~

200 pC +os g M ggi 0

0.0 0.5 1.0 . 1.5 '2.0 2.5 3.0 3.5 4.0 TIME SECONDS

0 60.20 60.10 60.00

~wtr <<0 J <<N~o

X .

~

~ ~ ~

we

59. 90

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~ ~ ~ / 0 59.80

59. 70 FREQUENC'2 DEPARTURE LOSS OF "URKE'l POINT 4-:,i0()HN)

FRAGiME¹'ZD "HANSYi SSION SYSTEM rSS-.7-4A2 59.60 Turkey Poinr 3 Crystal R ver 3 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~

Big Bend 2 Ina'an R='ze Northside 3 59.50 0.0 0.5 l.0 l.5 2.0 TIME SECONDS

600 500 400 30 Z

I r 4/

//

g 20 0

/ /

/

4 /

/

LINE FLON SOUTH LOSS OF TURKEY POINT 4 (700MW)

FRAGMENTED TRANSMISSION SYSTEM TSS-77-4A2 Total Suwannee-Archer 230kV-

-10 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 TIME SECONDS

APPENDIX 8 APPENDIX B FPC REPORTS ON ELECTRIC POWER DISTURBANCES DURING: THE SECOND QUARTER OF 1977 APRXL 1 JUNE 30, 1977 The Federal Power Commissi:on (FPC) requires all electric

-utilities to report electric power disturbances under Order 331-1. The reports 'are classified into three categories; bulk power supply interruptions which, result in loss of ultimate customer load, load reduction measures which do not necessarily result in disconnection of customer load, and events which constitute an unusual hazard to bulk electric power supply=

The second quarter of 1977 reported disturbances are briefly summarized for each classification in attached Tables I, XX, and XXX. The major disturbances are described in greater detail below:

I

Bulk Power Su 1 Xnterru tions r

During the second quarter of 1977, the nation's electric utility systems reported eight bulk power supply interruptions to, FPC.

P FPC Order No, 331-1 requires electric systems to report all interruptions of bulk power supply caused by'he outage of any generating unit or electric facility operating at a nominal

. voltage of 69 .kilov'olts or higher and resulting in a load loss for 15 minutes or longer. of at least 100 megawatts.' Smaller must report i 5 one-half or more of the annual system 'ystems peak load is involved. The major interruptions are described below.

Florida Power and Light Co. Nay 16, 1977 Tne largest bulk electric power interruption in terms of customers and load occurred on Hay 16, 1977, when 1,300,000 customers, representing 3,227 megawatts of load, were deprived of service for periods up to four hours and 36 minutes during an outage on Florida Power a Light Company's (FP&L) system During this period, three, separate incidents of system dis-turbance occurred, which are categorized as:

l."-"aForced outage of Turkey PoinC Unit No. 3, 666-megawatt nuclear unit.

2. Loss of the FC. Myers-Ranch 240-kilovolt transmission line;" and

3. Loss of the Andytown-Orange River 500-kilovolt line. r At 10:08 a.m.'. Turkey Point Unit No. 3 experienced a reactor and turbine trip as the result of a false relay signal

.which caused the loss of 684 megawatts in generation. The north-south lines in the State of Florida relayed, isolating the Peninsula from the north. The combined spinning reserves of the Florida system were sufficient to cover the loss and arrest the frequency decline- at 59 59 hertz, .and no customer service was affected At 10:14 a.m. the interconnection to

.the north was re-established and the frequency returned to 60 hertz. However, with the loss of Turkey Point: No. 3,'he system transmission line loadings were such that the Ft.

line was loaded to its maximum thermal-ratingNyers-Ranch'40-kilovolt Ten minutes later, a second outage, which extended from Fort Pierce southward alon'g the East Coast to the Florida Keys',

was triggered when the heavily loaded (west to east flow) Ft.

Myers-Ranch 240-kilovolt line tripped because of a phase-to-ground fault. This caused heavy north to south flows tripping

. other key transmission lines. This division of the transmission system resulted in the St. Lucie Plant of the eastern area being tied only to the northern system area, tne Riviera Plant being islanded with part of the eastern system area load, and creation of an isolaCed southern area.

In the southern area, Port Everglades Units 1 and 3 and Turkey Point Units 1 and 2 were generating a total of 1,003 megawatts to supply approximately 2,950 megawatts of load. ~

This load-generation imbalance caused a rapid decrease in frequency to below 56 hertz. Underfrequency relays operated

'to shed approximately '1,544 megawatCs of load. The four units operating at Port Everglades and Turkey Point Plants became overloaded and tripped out due to underspeed protection., Tne isolaCed eastern area's Riviera Plant was shut down because of excess generation and subsequent operaCional problems following rapid unloading.

B-2

The other FP&L system, islands, (north and west) went into

- overfrequency from excess generation causing tne St., Lucie Unit 1 operator to manually trip the nuclear unit due to rapid unloading to an unsatisfactory level. Shortly the frequency in the north and west recovered to normal, which permitted re-establishment of the north-south PP&L system ties and reconnec-tion to other Florida systems The total number of customers affected by this series of events was 1,300,000, representing 3,227 megawatts of load. Restoration of the south and eastern areas began and most of the load was re-es'tablished by 12:03 p.m.,'fter one hour and 39 minutes.

During ~his initial restoration at, 12:03 p.m. the third incident occurred when the Andytown-Orange 500-kilovolt line tripped because of the misoperation of a fault pressure relay on the "A" phase of the 240/500-kilovolt autotransformer at Andytown. This initiated a power swing which resulted in the separation of the entire eastern and southern areas at Nalabar.

Generation in the affected area was again separated by under-frequency generator protection and overcurrent relay operation.

The total amount of load lost was 2,025 megawatts. Service restoration again proceeded immediately. Gas turbines quickly picked up load in the isolated areas and were synchronized with the northern system. Service was restored to all but a few small isolated areas by 3:00 p.m. the same. day;

'I i Tennessee Valley Authority tlay 2," 1977 Zn terms of load, the second largest bulk electric power interruption occurred on Nay 2, 1977, on the Tennessee Valley Authority's (TVA) system when the loss of two Electric Energy Tnc. 161-kilovolt transmission lines supplying load to the Energy Research-and Development Administration (ERDA) in Paducah, Kentucky, caused the loading and tripping of a TVA 161-kilovolt.

circuit to the ERDA load center Following loss of the TVA circuit from its Shawnee plant, three of the plant's units tripped, resulting'n a power interruption which lasted for

.five hours and 29 minutes and a load loss totaling 1,0S4 mega-watts. Only one industrial customer, ERDA, was affected by the outage.

h B-3

APPENDIX C Sample Calculation Area Load Chart Transmission System Breaker Diagram 4/1/77 (8 sheets)

Transmission System Schematic Diagram Oscillograms Broward (1 roll)

Oscillograms Midway (1 roll)

CNW:sh 3/30/78 SAMPLE OF CALCULATION OF FT. MYERS-RANCH 240l<V LINE LOADING APPROX I MATE TAMPA Tl ES MANATEE FT. MYERS POWER AREA FORT MYERS " RANCH FLOWS Tl 82 .

m $31 P2 GT AVAILA8LE LOAD TOTAL 240kV LINE 10:07 -70 105 585 . 108 337 0 995 705 290 191 10:08- -180 20 638 128, 346 0 1272 . 710 562 395 10:23 -180 20 677 128 365 5 1335 740- 595 420 10:24 70 '50 570 107 310 5 672 672 0 0

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FLORIDA POWER 8 I.IGHT COMPANY Cl 'L22'I TO TURKEY POINT DAVIS FLAGAMI Sf f SHEET- I 'IO FLAGAMI TO COCONUT GROVE

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APPENDIX D Total Generation Chart Relay Settings (Fort Myers Ranch)

R-X Diagram Phase Relays (Fort Myers Ranch)

Matt-Var Diagram Phase Relays (Fort Myers Ranch)

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12/10/76 PL-435 STATION FLORIDA POWER 8 LIGHT COMPANY FT. MYERS CIRCUIT FT. MYERS-RANCH 240kV PROTECTlVE RELAY SETTINGS COMPANION PANEL PB-128 Indicates change from specified settings dated Circuit Impedance: 11.17 +j 77.27 Ohms Carr i er Channel Frequency: 106 kHz

": 007 Ratio: '000/5 CLPG Relay is DUAl Pol ar ized,,

PT'Ratio: 2000/1 CEY Phase Carrier Trippin ReLa CLPG Ground Carrier'Rela Model Number: 12CEY54A1D. Model Number: 12CLPG12ClA Range: 1 - ~0 Onms . Range:- Gl 0.4 " 1.6 Amps A

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Settings:

Basic Tap: ~ Ohms Approximate Restraint Tap:

Reach: 20:0 Ohms 18 %..

Settings:

G1 G2 G2 ~0.

Pickup: 0.4 Amp s Pickup: 0.6 Amps

- 2.0 Amps Augie: GD Pickup: ~0.2 ixl ~ ~6 Exl GD Test Amps With Coil in Series: 0.5 CEB Phase Carrier Blockin Rela 00 Test VA P Unit Power Factor: 20.7

~3 Model Number: 12CEB52A10 Range: 1 - 30 Ohms CEB Out-Of-Ste Detection Rela Settings Basic Tap: 3 Ohms Range: ~30 Ohms g Approximate Restrain't; Tap: 12%. 75'ettings:

Ohms Reach: 0-5 Angle: Approximate Restraint Tap: 1(P/,

Reach: ~2 ~ Angle: 240 Ohms Reach: ~2.60 Ang'le: ~20 9o'hms A

~s Forward Reach: 26.0 Ohms

,Angle: 75' Backward Reach: 4.0 Ohms-

'HC Angle:

Phase Carrier Fault Detector Rela Model Number: 12CHC12A2A Range: 2 8 Amps Pickup: 2 Amps 255'ELAYS SET AS SPECIF IEO By Date FORM 3102 REV. 3/75

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