ML17207A755
| ML17207A755 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 01/15/1980 |
| From: | Robert E. Uhrig FLORIDA POWER & LIGHT CO. |
| To: | Harold Denton Office of Nuclear Reactor Regulation |
| References | |
| RTR-NUREG-0578, RTR-NUREG-578 L-80-24, NUDOCS 8001220409 | |
| Download: ML17207A755 (20) | |
Text
REGULATORY INFORMATION DISTRIBUTION SYSTEM (HIDS)
ACCESSION NBR ~ 8001220409 DOC ~ DATh! 80/01/15 NOTARIZED:
NO F'AGLC:50 335 St, "Lucie P
1 ant i Uni t i z Florida Power L L)ght Co, AOTH, NAME AU'THOR AFFILlA'TION UHHIG, H ~ E e Florida Power L Light Co, HEGIP,NAME RECIPIENT AFFILIATION DEATUAgH~ R ~
Office of Nuclear Reactor Regulation DOCKET 0'5'000335
SUBJECT:
Forwards info'n response to NRC 80010 'trgre power reliability,Requests extension of implementation of NUHBG 0578 Category A requirements beyond 800215
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FLORIDA POWER IL LIGHTCOMPANY January 15, 1980 L-80-24 Office of Nuclear Reactor Regulation Attention:
Harold R. Denton, Director U. S. Nuclear Regulatory Commission Washington, D.
C.
20555
Dear Nr. Denton:
Re:
St. Lucie Unit I Docket No. 50-335 This letter is in response to your letter dated January 4, 1980 which requested information related io power reliability.
The information provided is based on current information and projections and could change as a result 'of subse-quent events.
Florida Power 8 Light Company believes there is a high probability that it will be necessary to seek an extension of the implementation of Category A
requirements beyond February 15,.1980 o-the basis of power reliability in Southeast Florida.
Any deterioration of our projected power reliability as depicted by the attached information would provide additional ju"tification for such an extension request.
The attached information is being submitted to aid you in your review for such an extension request.
We w'ill advise you imm diatoly of any significant changes in the attached information.
Very truly yours, Robert E. Uhrig Vice President Advanced Systems 8 Technology REU/GDW/ah Attachment cc:
J.
P. O'Reilly, Region II Harold F. Reis, Esquire pop/.
Lev g gyes I
80 0122'q, PEOPLE... SERVING PEOPLE
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COUNTY OF DADE STATE OF FLORIDA
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ss Robert E. Uhrig, being first. duly sworn, deposes and says:
That he is a Vice President'f Florida Power 6 Light Company, the Licensee herein; That he has executed the foregoing document; that the state-ments made in this said document are true and correct to the best of his knowledge, information, and belief, and that he is authorized to execute the document on behalf of said Licensee.
Robert E. Uhrig Subscribed and sworn to before me this
/5 day of 19 J'5 NOTARY PUBLIC, in and fox the county of Dade, State of Florida NOTARY PIJBUC STATE OF FLORIOA st LARGE MY COhth1ISSION EXPIRES AUGUST 24, PI8I lIy commission exPires:
80NDED THRU MAYNARD BQNDING AGENcf
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~ XTE'4 Pr 1 1/ll/80 g.
A listing of all utility-owned (in whole or in part) generators and their expected availability and capacity to produce power.
indicate planned unit maintenance or other outage arid rationale for scheduling such outage at this time.
A listing of FPL's generating units is provided below.
Presently, FPL has three units, undergoing maintenance and/or scheduled refueling.
Manatee Unit Nl is being overhauled and is expected to be returned to service in the second half of January.
Turkey Point Unit I3 is being refueleQ and is expecteQ to be back to power at the'end of January.
Port Everglades Unit N4 is undergoing maintenance and repair and is presently expected, to be available in mid-February.
FPL considers oil conservation to be of primary importance to our nation.
Accordingly, we will be conducting a test program at one'of our Sanford units whereby a coal-oil mixture will be burned.
Modifications are required to be made to plant facilities to accomodate such a program.
Ne have scheduleQ Sanford Unit 84 to be brought off.
l the line in late February to make the required modifications.
This outage is expected'to last approximately" three weeks.
The effects of the outage of St. Lucie Unit Nl concurrent with the Sanford Unit g4 scheduled modifications arereflected in the reserve margin cal'culations provided in r'esponse to Xtem 9.
A calculation. of, system reserve for the outage of only St. Lucie Unit Nl is also provl.deQ Ne have not includeQ in our calculations the effects of gas turbine unavailability due to maintenance and have therefore not considered the effects of curtailable'oads as.~they tend to offset one another.
We have assumed the outage of Cape Canaveral 52 on February 3 for 3 weeks of maintenance and of Port Everglades 03 on February 24 for 7 weeks of maintenance, can be rescheduled to a later'ime in. the year.
This revised maintenance schedule is reflected in the calculations in Item 9 which would yield much lower reserve margins had these changes not been made.
TABLE 1 PPL SYSTEM GENERATXNG CAPACXTY 1/14/80 Unit Name Net Winter Continuous..
b Turkey Point 1
2 3
'iesels Lauderdale 4
5GT's Port Everglades 1
2 3
'Diesels GT' Riviera' 2
3 St. Lucie Ca e Canaveral Sanford Putnam Manatee 1
2 1
2 GT' Total Xnstalled Net Capabilit 2145.5 370 370 696 696 13.5 10'42 139 139 764 1547.5 206 206 370 370
- 13. 5 382 662 41 71 275 275 795 795 736 370 366 871 139 366 366 5.02 251 251 1550 775 775 1265 139 370 756
. 11166
XTEW 52.
Q.
A listing of all existing electric power purchase and.
sale contracts.
Also, identify any special purchase or sales of power that take place'.
Xndicate the specific applicability.
in megawatts of any of these contracts to the period of concern-A.
Florida Power 6 Light (FPL) has interchange contracts with other utilities within the state of Florida.
- However, no firm purchases of power are presently being made and none could be negotiated under these contracts on such snort, notice.
Xntercharges could occur under presently approved economy and emergency, schedules,
- however, the availability of such power is unpredictable and not guaranteed.
Even 'if power were available for purchase, reliability considerations dictate a maximum import, capability of 225 lÃ.'his, number is based on an import capacity of 100011M-reduced by. the output capacity of our largest unit, 775 M1.
(Assuming St. Lucie 1 is off.)
(See Xtem 10).
XTEM 63 Q.
A copy of any regional power sharing or reliability agreement indicating the specific applicability of any part of this agreement and provide detailed information regarding the possible impact of applicable load. curtailment plans.
A.
There is no reliability agreement within the state of Florida and no sharing of power other than interchange transactions,czs described in Xtem jf2.
NV 1/14/80 ITEN 54 Q.
The expected peak load-for each month for the period of concern, identifying any interruptible loads available.
Additionally, an analysis of the impact of adverse weather conditions on monthly peak demand should be supplied.
A.
The expected.
monthly peak load for the period of concern of 8990 FiN is reflected in the calculations in Xtem 59.
FPL has no interrupt'ible load.
FPL has approximately 175 MN of curtailable load.
This curtailable load is not separately shown on the calculations in Xtem.59Table 52 since, for the sake of simplicity, it was assumed this load is directly offset by an equivalent amount of gas turbine capacity which is continuously out for maintenance (see. Xtem gl and.
Xtem $ 9).
l/la/80 XTEM 55 Q-A description of any expected system transmission line loading, voltage control; or system stability problem.
Xdentify any extended transmission line or generating unit voltages which may have an impact.
A.
Southeast Florida is that, area bounded by St. Lucie County on the north, the Florida Everglades on the west, and Dade County on the south.
This area encompasses approximately three million people and nearly 70 percent of the total PPL load.
The total generating capacity of the area's five active power plants is less than the total area load.
As a result., the area is, perenially dependent on its transmission interconnections one 500 kV and one 230 kV line to the west, and two 230 kV lines to the north--to serve its needs.
Because'f its size, natural boundaries, and dependence on external transmission, Southeast Florida has unique reliability and transient stability characteristics.
Accordingly, FPL attempts to operate and control this area within carefully defined limits.
After considerable study and operating experience, it has been established that, to consistently maintain an acceptable level of reliability within Southeast Florida and reduce the likelihood of system islanding, total transmission flows into Southeast Florida must be controlled to a level equal to (1500 NW minus the largest area generating unit).
Since the largest generating unit. within this area is typically St. Lucie Nl (795 NN) or Turkey'oint 83 or 14 (696 H<7 each), total transmission flows are thereby typically constrained to 700-800 NÃ.
Item 55 (continued)
This operating practice ensures that, for the sudden loss of a large Southeast Florida generating unit, all transmission flows, stability limits, and. voltages remain within long term ratings.
Moreover, for more serious disturbances, the likelihood of system islanding is substantially reduced, if not avoided.
Table 2
shows Southeast Florida generating reserves under different operating conditions.
As shown<
loss of St. Lucie fl causes reserves to fall to 4l-Negative reserves mean the above described liniit is violated and conse'quently the reliability risk associated with any disturbance increases accordingly.
e GRC/1-14-80 Item IG The level of current fuels inventories, an assessment of the adequacy of fuel supplies to meet energy requirements during planned nuclear outage, and the expected..impact of the nuclear unit. outages on these levels.
Current and projected fuel inventories are adequate.
0 Xtem. I7 A description of any expected imp'act on the regional power supply network.
Assuming the "regional" network refers to Peninsular
- Florida, FPL has not attempted to estimate the impact of the outage of St. Lucie Il on Peninsular Florida.
FPL understands,
- however, the Florida Electric Power Coordinating Group (FCG), which represents most Florida electric utilities, at the request of DOE, has submitted data describing expected
\\
impact on a Peninsular Florida basis.
The data was submitted to:
Mr. Richard E. Neiner Director, Division of Power Supply 8 Reliability Economic Regulatory Administration U.S. Department of Energy 2000 M. Street, N.H.
washington, D.C.
20461 4
through'ransmittal letter dated January 10, 1980 from
'ichehl R. Gent, General Manager of the FCG.
ITEM 58 0
NV
'/14/80 A weekly compilation of the utility's net energy for load 'for the projected outage period and for the same time period of the previous year (includes details on generation, purchases and
- sales, and anticipated load).
Provide details on any load management or similar activity which might cause significant variations in customer energy requirements.
A.
PPL's 1980 estimated and 1979 actual net enexgy for load for the period of concexn are given below.
These figures assume no interchange transactions but do include wholesale sales under our Paxtial Requixements (PR) and Sale for Resale
'(SR); rates.
Ne do not generally keep the requested information on a weekly basis,
, rather, we keep it, on a monthly basis.
Accordingly, we h'ave assumed that the load is evenly distributed. throughout the month in compiling the data presented below.
1979 Met Energy Por Load Time Period Energy(Million kNH) 2/1-2/3 2/4-2/10 2/11-2/17 2/18-2/24 2/25-3/3 337.38 787.22
'787.22 787.22 736.56 1980 Estimated Net Ener for Load Time Period.
Enermr (Million kYiH) 2/1-2/2 2/3-2/9 2/10-2/16 2/17-2/23 2/24-3/1 241 844 844 844 833
e GRC/1-14-80 Item 09 A calculation of the anticipated minimum generating reserve margin during each week of the period.
The minimum reserve margin shall be calculated as the generating capacity in megawatts available to supply load above the anticipated system peak load for the week.
(This calculation should consider system power sales and purchases.)
Please relate the reserve margin calculation to its corresponding loss of load probability.
Table 2 calculates reserve margins for FPL and Southeast Florida for different time periods and under the, stated operating conditions; A 20 percent reserve margin is generally regarded by the electric utility industry and by those government.
agencies responsible for reviewing reliability standards, as the minimum reserve level which should be maintained by systems such as FPL to insure adequacy of generation supplies.
The 20 percent reserve margin is essential to protect against unscheduled generating
- outages, unit deratings, and other contingencies; as well as to maintain, and when necessary supply',
'spinning reserve commitments.
An examination of Table 2 reveals that, even under the most favorable conditions i.e., only St. Lucie 51 out of service, 'and all other FPL units fully available reserve margins for FPL's system and for Southeast Florida fall below 20 percent (17.3 percent and 4 percent respectively).
Under more realistic operating conditions--
i.e., either Port Everglades 54 or Sanford 54, in addition to St. Lucie Nl, out of service reserve margins for FPL fall to approximately 13 percent and for Southeast Florida
Item N9 (continued) become negative.
It should be noted that additional units were originally scheduled for maintenance during the period of concern (as described in Item Nl) and it >was assumed that, where
- feasible, maintenance for these units will be rescheduled for a later date.
Therefore, Table 2 reflects maintenance schedules already adjusted to minimize the impact of an unexpected.
outage of St. Lucie 51.
As regards LOLP, FPL, as well as other FCG utilities,,
analyzes and calculates LOLP on an annual basis.
The data base and analytic 'tools readily available to FPL or the FCG to calculate LOLP do not lend'hemselves to weekly or even monthly calculations of LOLP.
In prior LOLP evaluations of the FPL and the FCG
- systems, it. has been determined that acceptable LOLP
- indices, whether for FPL or for Peninsular Florida, generally correspond to FPL reserve margins above 20 percent.
TABLE 2 MV 1/14/80 FPL SYSTEM 2/15-3/1 2/15-3/1 11,116 11,116 Installed Time Period
= Gen. Capacity 2/1-2/15 ll;116 Maintenance 1,165 795 1,161 Net Dependable Ca acity 9,951 10,321 9,955 Transmission Imports 225 225 225 Total Sources Load 10,176 8,990 10/ 546 8 g 990 10'80 8 ~ 990 Reserves (i')
( % )
1186 13.
1556 17.3 1190 13.2 SOUTHEAST'LORIDA 2/1-2/15 2/15-3/1 6,
192',192 1,165 795 5,027 5,397 804 804 5,831 5,979 6 g 201 5 / 979 (148)
(3).
222 Units Out:
2Units Out:
Units Out:
4Units Out:
5Units Out:
St. Lucie 1, Pt. Everglades 4
St. Lucie 1 St. Lucie 1, Sanford 4
St. Lucie 1, Pt. Everglades 4
St. Lucie 1
GRC/1-14-80 Xtem,610 A statement.
on the availability of emergency support from contiguous control areas, indicating size of potential support and conditions 'on availability.
The total estimated import capability of the FPL system from the interconnected network is approximately 1000 KV.
To protect against the 'sudden loss of a la'rge FPL generating unit and -preclude more serious consequences, FPL must "reserve" out of this total import capability l
an amount equal to the largest FPL generating unit.
Accordingly, the analy'sis assumes FPL could purchase (and neighboring systems can collectively sell), on a firm basis, an amount equal'to the remaining import P
capacity (1000 HW minus the largest FPL generating unit).
This is the amount used for. calculation purposes in Table 2.