SYSTEM IMPACT STUDY FOR THE ANCLOTE REPOWERING … · 2019-12-19 · 1. LRS Pass 5 case 2. Two 1120 MVA autos at CFLA (already in case) 3. Existing Anclote Units @ max 4. Bartow,

SYSTEM IMPACT STUDY FOR

THE ANCLOTE REPOWERING

PLANT – PHASE I

STEADY STATE AND SHORT

CIRCUIT ANALYSES

OCTOBER – 2012

TRANSMISSION PLANNING

October 2012 Anclote Phase I Combined Cycle Plant SIS Page 2

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Executive Summary The proposed Progress Energy Anclote Phase I Repowering Plant consists of a combined cycle

power plant composed of three new combustion turbines and the existing Anclote 1 steam unit.

The total summer and winter net output of the Plant is 1200 MW and 1400 MW, respectively

with a 0.90 PF. The Plant will interconnect to the Progress Energy Florida 230 kV system at the

existing Anclote substation in Pasco County, Florida. The current proposed in service date for

the Plant is summer 2016.

The results of the steady state and short circuit analyses indicate that the addition of the Plant, its

associated reinforcements and required transmission system upgrades will have no significant

impact on the steady state and short circuit responses of the bulk transmission system as well as

on the import capability of the Southern – Florida interface. The interconnection of the proposed

Anclote Phase I Repowering Plant will include new transmission facilities and the upgrade of

several existing transmission facilities identified in the steady state and short circuit studies.

The following are the transmission facilities identified in the steady state and short circuit studies

directly related to the interconnection:

New breaker-and-a-half four bay 230 kV Gulf Pine Substation

Two new breaker-and-a-half bays 230 kV at existing Anclote Substation

New Anclote – Gulf Pine 230 kV 2-bundle 795 ACSS/TW

Rebuild Anclote Seven Springs 230 kV with 2-bundle 795 ACSS/TW

Looping of 230 kV Seven Springs-Brookridge and Seven Springs-Lake Tarpon into

Gulf Pine Substation

Upgrade Seven Springs 230 kV Substation to 3000A

Remove limiting elements in the Seven Springs 115 kV bus.

Rebuild 115kV Brookridge-Crystal River South with 1622 ACSS/TW, 19.26 miles

Rebuild 115 kV Spring Hill-Heritage Tap with 1622 ACSS/TW, 4.83 miles

Assume the Brooksville/Brooksville W expansion project in service

Upgrade Brooksville 112 MVA transformer up to 168 MVA

Remove limiting elements at East Clearwater 230/115 transformer, Hudson-Gulf Pine

230 kV, Lake Tarpon-Sheldon Road Ckt2 230 kV and Central Florida-holder 230 kV.

New 115 kV 2x25 MVar cap bank at Brookridge

Rebuild Wildwood City Tap-Dallas Airport Tap-Dallas Airport 69 kV with 1272

ACSS/TW, 8.6 miles

Rebuild 69kV line segments from Brooksville to Consolidated Rock Tap to Croom

Tap to Bushnell with 1272 ACSS/TW, 20 miles

Rebuild Leesburg East-Leesburg 69 kV with 1272 ACSS/TW, 1.1 miles

Upgrade 64 over-dutied circuit breakers

The total gross estimate to interconnect the Anclote Phase I Repowering Plant to the Progress

Energy transmission system is $160M. This cost estimate includes $9M for the transient

stability upgrades provided in a separate report.


Table of Contents

Executive Summary ___________________________________________________________ 3

Table of Contents _____________________________________________________________ 4

Introduction _________________________________________________________________ 5

System Representation ________________________________________________________ 7

Base Case Steady State Models _______________________________________________________ 7

Short Circuit Models ________________________________________________________________ 7

PV Analysis Models ________________________________________________________________ 7

Generator Interconnection Queue Considerations________________________________________ 8

Transmission Service Request Priority List Considerations _________________________________ 8

Methodology ________________________________________________________________ 9

Steady State Analysis _______________________________________________________________ 9

Short circuit analysis _______________________________________________________________ 9

PV voltage stability analysis __________________________________________________________ 9

Evaluation of System Response to Normal and Contingency Conditions ________________ 10

Thermal Analysis Results Screening Criteria. ___________________________________________ 10

Voltage Analysis Results Screening Criteria. ____________________________________________ 10

Short Circuit Analysis Results Screening Criteria. ________________________________________ 10

PV Analysis Results Screening Criteria. ________________________________________________ 10

Discussion of Study Results ____________________________________________________ 11

Steady State Thermal and Voltage ___________________________________________________ 11

Short Circuit _____________________________________________________________________ 12

Third-party Impacts _______________________________________________________________ 13

PV Analysis ______________________________________________________________________ 13

Costs ___________________________________________________________________________ 13

Appendix A ______________________________________________________________________ 14

Appendix B ______________________________________________________________________ 22


Introduction

Progress Energy Florida is proposing the construction of a combined cycle power plant with a

total summer and winter net output of 1200 MW and 1400 MW, respectively with a 0.90 PF.

The proposed Anclote combined cycle plant consists of three new combustion turbines and the

existing Anclote No 1 steam turbine. The station service load will be 51 MW, 0.80 PF. The

Plant will interconnect to the Progress Energy Florida 230 kV system at the existing Anclote

substation in Pasco County, Florida. The current proposed in service date for The Plant is

summer 2016.

This Generation Interconnection System Impact Study evaluated steady state and short circuit

system performance. The transient stability system study is available in a separate report. The

impact of other relevant proposed generation projects in the study area was considered in this

study. Analysis for the Plant and its impact on the Florida bulk transmission system was

performed in accordance with, FERC Large Generation Interconnection Rules, NERC/FRCC

Reliability Standards, and Progress Energy Florida Interconnection Requirements.

The next two Figures show the proposed interconnection of the Plant to the existing Anclote 230

kV bus and the one line diagram of the local area under study.

Proposed Interconnection of the Plant


7 SPRINGS

230.kV

7 SPRINGS

115.kV

ANCLOTE

230.kV

ANCL COOL

230.kV

ANCLOTE G2

22.kV

ANCL-STA

22.kV

BKVW

230.kV

BROOKRIDGE

230.kV

CURLEW

230.kV

E CLEARWATER

230.kV

HUDSON

230.kV

LARGO

230.kV

LAKE TARPON

230.kV

SHADY HILLS

230.kV

SHADY HLS P1

18.kV

SHADY HLS P2

18.kV

SHADY HLS P3

18.kV

ULMERTON

230.kV

GULF PINE

230.kV

BKVL

230.kV

BKVL

115.kV BKVW

115.kV

ANCL-CTA1

19.kV

ANCL-CTA2

19.kV

ANCL-CTA3

19.kV

One Line Diagram of the Local Area


System Representation

Base Case Steady State Models

The steady state models were based on the FRCC 2011 library cases. The years studied for

power flow and voltage analyses were 2016 summer and 2016/2017 winter. The following Table

shows in more detail the dispatch scenarios:

Base Case

Anclote Phase I

Repowering

2016

Summer

1. LRS Pass 5 case 2. Two 1120 MVA autos at CFLA

(already in case) 3. Existing Anclote Units @ max 4. Bartow, Bayboro, Higgins @ max 5. Reduce Debary, Intercession, Hines 4 6. Use CR 5 as area swing bus

1. All assumptions in the base case 2. Anclote Unit 1 repowered 3-on-1,

plant net output is 1200 MW. 3. Shut off Hines 3 & 4.

2016/17

Winter

1. LRS Pass 5 case 2. Two 1120 MVA autos at CFLA

(already in case) 3. Existing Anclote Units @ max 4. Bartow, Bayboro, Higgins @ max 5. Reduce Debary, Suwannee, HERO 6. Use CR 5 as area swing bus

1. All assumptions in the base case 2. Anclote Unit 1 repowered 3-on-1,

plant net output is 1400 MW. 3. Shut off Debary, Intercession 4. Reduce Hines 4 to near Pmin

Short Circuit Models

The short circuit analysis performed by PEF’s Bulk Transmission Planning utilized the FRCC

2010 series final short circuit models. The model year studied for short circuit analyses was

2016.

PV Analysis Models

The PV analysis was performed using the FRCC 2011 cases with the Southern – Florida transfer

import at 3700 MW for 2015 summer. This analysis was performed to determine the impact of

the new plant on the import capability of the Southern – Florida interface.


Generator Interconnection Queue Considerations

There are no prior queued generator interconnection requests in the study area that might have a

potential impact on the results of this study.

Transmission Service Request Priority List Considerations

All relevant transmission service requests with queue priority in the study area were modeled in

the base case.


Methodology

Steady State Analysis

The base cases and the corresponding Anclote Phase I Repowering interconnection cases were

compared to determine if the new Plant interconnection created thermal overloads or voltage

violations, or exacerbated existing thermal overloads or voltage violations.

The following contingencies were studied:

All single element NERC Category B contingencies in the central-west and northern

portion of the FRCC region

NERC Category C2 and C5 contingencies within the FRCC region as specified by FRCC

transmission owners

NERC Category C3 contingencies in the vicinity of the interconnection

C3 contingencies were screened by simulating all possible double contingencies within a bus

subset near the point of interconnection. All branch flows and bus voltages in the central-west

and northern portion of the FRCC region were monitored.

Short circuit analysis

The short circuit analysis was performed using PSS/E. Three phase and single line-to-ground

faults were applied at all buses within 6 buses of the Anclote 230 kV bus. Fault analyses were

performed according to the Progress Energy short circuit criteria.

PV voltage stability analysis

The PV analysis was performed using the PSS/E PV engine. Select contingencies known to have

the greatest impact on the import and export capability of the State of Florida were examined.


Evaluation of System Response to Normal and

Contingency Conditions

Thermal Analysis Results Screening Criteria.

System-intact overloads must be greater than 100 percent of rate A to be reported.

Post-contingency overloads must be greater than 100 percent of rate B to be reported.

Post-contingency overloads that are improved by the interconnection were excluded.

Post-contingency overloads must have been made worse than the base case by 3% of the

affected element’s rating or greater to be reported.

Voltage Analysis Results Screening Criteria.

Buses in PEF and SECI were monitored for values outside of the range 0.9 – 1.05 p.u.

FPL 69, 115, 138, and 230 kV buses were monitored for values outside the range 0.95-

1.07 p.u.

FPL 500 kV buses were monitored for values outside the range 0.95-1.09 p.u.

TECO 69 kV buses were monitored for values outside the range 0.925-1.05 p.u.

TECO 138 and 230 kV buses were monitored for values outside the range 0.95-1.06 p.u.

Crystal River Plant 230 kV bus voltage should remain above 232.4 kV, or 1.0104 p.u.

Turkey Point bus voltage should remain between 1.01 p.u. and 1.06 p.u.

St. Lucie bus voltage should remain between 1.00 p.u. and 1.06 p.u.

All other monitored areas were monitored for values outside of the range 0.95 – 1.05 p.u.

Absolute change in bus voltage between base case and the interconnection case must

have been greater than 0.01 p.u to be reported.

Short Circuit Analysis Results Screening Criteria.

Three phase and single line-to-ground fault current on the PEF system had to exceed the

interrupting rating capability of the breaker to be considered for upgrade.

Three phase and single line-to-ground fault current results and short circuit cases will be

provided to third parties relevant to the area under study for their own evaluation

according to their breaker rating criteria.

PV Analysis Results Screening Criteria.

The Anclote Phase I Repowering Plant might not have an adverse impact on the transfer

capability of the Southern – Florida interface.


Discussion of Study Results

Steady State Thermal and Voltage

The following are the new and existing facilities upgrades impacted by the Anclote Phase I

Repowering Plant identified in the steady state analysis:

New breaker-and-a-half four bay 230 kV Gulf Pine Substation

Two new breaker-and-a-half bays 230 kV at existing Anclote Substation

New Anclote – Gulf Pine 230 kV 2-bundle 795 ACSS/TW

Rebuild Anclote Seven Springs 230 kV with 2-bundle 795 ACSS/TW

o Common ROW, not on common structures between Anclote and Seven Springs

Looping of 230 kV Seven Springs-Brookridge and Seven Springs-Lake Tarpon into Gulf

Pine Substation

Upgrade Seven Springs 230 kV Substation to 3000A

Remove limiting elements in the Seven Springs 115 kV bus.

Rebuild 115kV Brookridge-Crystal River South with 1622 ACSS/TW, 19.26 miles

Rebuild 115 kV Spring Hill-Heritage Tap with 1622 ACSS/TW, 4.83 miles

Assume the Brooksville/Brooksville W expansion project in service

Upgrade Brooksville 112 MVA transformer up to 168 MVA

Remove limiting elements at East Clearwater 230/115 transformer, Hudson-Gulf Pine

230 kV, Lake Tarpon-Sheldon Road Ckt2 230 kV and Central Florida-holder 230 kV.

New 115 kV 2x25 MVar cap bank at Brookridge

Rebuild Wildwood City Tap-Dallas Airport Tap-Dallas Airport 69 kV with 1272

ACSS/TW, 8.6 miles

Rebuild 69kV line segments from Brooksville to Consolidated Rock Tap to Croom Tap

to Bushnell with 1272 ACSS/TW, 20 miles

Rebuild Leesburg East-Leesburg 69 kV with 1272 ACSS/TW, 1.1 miles

Appendix A lists in detail the results of the steady state analysis. In addition to the upgrades and

topology changes listed above, the following Table lists the proposed mitigation actions under

various contingency conditions:


Overloaded Element(s)

Contingency Conting

ency Type

Overload Magnit

ude Mitigation

Gulf Pine-Anclote 230 kV *

Anclote-Seven Springs 230 kV & East Clearwater-Anclote 230 kV

C3 N-1-1 104.1% Reduce output at ANCL 2

Bushnell East-Croom Tap 69 kV Croom Tap-Consolidated Rock Tap 69 kV Consolidated Rock Tap-Brooksville 69 kV Crystal River-King Road Tap 230 kV

Central Florida-Holder 230 kV & Holder-Ross Prairie 230 kV

C2 108.8% 110.2% 110.2%

100.8%

Open line at Bushnell East end Reduce output at CR 1 or 2

Hudson 230/115 kV transformer 2 Hudson 230/115 kV transformer 1 & Hudson 230/115 kV transformer 3

C2 103.1% Split Hudson 115 kV bus at breakers 6649, 2635, 2633

Crystal River Plant-Holder 230 kV Ckt 1

Crystal River-Holder 230 kV Ckt 2 OR Crystal River-Holder 230 kV Ckt 2 & Holder 230/69 kV transformer

B

C2

106.2%

105.7%

Reduce output at CR 1 or 2

Crystal River Plant-Holder 230 kV Ckt 2

Crystal River-Holder 230 kV Ckt 1 OR Crystal River-Holder 230 kV Ckt 1 & Holder 230/69 kV transformer

B

C2

106.2%

105.7%

Reduce output at CR 1 or 2

Haines Creek-Sorrento 230 kV Camp Lake-Central Florida 230 kV & Clermont East-Central Florida 230 kV & Clermont East-Metro West 230 kV

C5 103.8% Reduce output at CR 1 or 2

Crossroads-Pasadena 115 kV Disston-Kenneth City 115 kV Pilsbury-Vinoy 115 kV

Largo-Seminole 230 kV & 40

th Street-Northeast 230 kV

C3 N-1-1 103.9% 114.8% 108.0%

Increase output at Bayboro peakers

16th

Street-40th

Street 115 kV 40th

Street-Northeast 230 kV & Northeast-Pilsbury 115 kV

C3 N-1-1 104.9% Increase output at Bayboro peakers

Cypress Wood-Dundee 69 kV Intercession City-Cane Island 230 kV

Haines City East-Dundee 230 kV & Citrus Center-Dundee 230 kV

C5 106.3% 113.1%

Increase output at Intercession City if necessary

West Lake Wales-Dundee 230 kV Ckt 1 West Lake Wales-Dundee 230 kV Ckt 2 Intercession City-Cane Island 230 kV

West Lake Wales-Dundee 230 kV Ckt 1 & West Lake Wales-Dundee 230 kV Ckt 2

C5 101.3% 104.2% 119.2%

Increase output at Intercession City if necessary

Fort Meade-West Lake Wales 230 kV Hines Energy-West Lake Wales Ckt 1 & Hines Energy-West Lake Wales Ckt 2

C5 103.1% Increase output at Intercession City and reduce output at Hines

Inglis 115/69 kV transformer Crystal River Plant-Holder 230 kV Ckt 1 & Crystal River Plant-Holder 230 kV Ckt 2

C5 101.3% Reduce output at CR 1 or 2

Intercession City-Cane Island 230 kV

Haines City East-Intercession City 230 kV & Citrus Center-Dundee 230 kV

C5 105.8% Increase output at Intercession City if necessary

Short Circuit

The short circuit analysis identified the impact on several circuit breakers by the new Anclote

Phase I Repowering Plant and its associated new and upgraded facilities. The next Table list a

summary of the circuit breakers impacted by the interconnection of the Anclote Phase

Repowering Plant. Detailed short circuit analysis results are presented in Appendix B.


Breaker

Voltage

Class

(kV)

Total

Number of

Breakers

69 18

115 19

230 27

Total 64

Third-party Impacts

A number of potential third-party thermal or voltage impacts were identified. These are listed

near the bottom of the table in Appendix A and will need to be evaluated by the Florida

Reliability Coordinating Council’s (FRCC) Transmission Working Group (TWG) during the

Regional Reliability review.

PV Analysis

The PV analysis results indicate that the Anclote Phase I combined cycle plant interconnection

will not have a negative impact on the import capability of the Southern – Florida interface.

Costs

The following is the gross estimate of the cost to interconnect the Anclote Phase I Repowering

Plant to the Progress Energy Transmission System:

Steady state upgrades: $131M

Short circuit upgrades: $20M

Transient stability upgrades: $9M

Total gross estimated costs: $160M

This cost estimate includes $9M for the transient stability upgrades provided in a separate report.

Any changes or modifications to the present proposal will require additional study work to

identify new impacts to the transmission system.


Appendix A

Anclote Phase I Repowering Steady State Results

Summer STRESSED Dispatch Winter STRESSED Dispatch

ContingencyAlias Affected_Element Rating

2016S_BASE Thermal_Effects

MWPostCont


PercentOL

2016S_1RP Thermal_Effects

MWPostCont


PercentOL OL_Diff Rating

2016W_BASE Thermal_Effects

MWPostCont


PercentOL

2016W_1RP Thermal_Effects

MWPostCont


PercentOL OL_Diff

PEF_C5-5 2068 HAINES CREEK230.00 TO 2072 SORRENTO 230.00 CKT 1 438.0 399.1 93.0 443.2 103.7 10.7

PEF_C5-47 2109 CAMP LAKE 69.000 TO 2124 MINNEOLA 69.000 CKT 1 122.0 161.6 131.2 176.1 143.5 12.3



PEF_BPRO-5 2109 CAMP LAKE 69.000 TO 2124 MINNEOLA 69.000 CKT 1 122.0 128.3 104.7 133.1 108.6 3.9

SG2113>2164>$1 2109 CAMP LAKE 69.000 TO 2124 MINNEOLA 69.000 CKT 1 122.0 123.3 100.2 127.4 103.6 3.4

PEF_C5-47 2112 CLERMONT 69.000 TO 2124 MINNEOLA 69.000 CKT 1 122.0 142.4 115.7 157.1 128.0 12.3

PEF_C5-GULFP 2267 E CLEARWATER230.00 TO 2269 LK TARPON-A 230.00 CKT 1 438.0 623.7 139.9 438.0 667.2 149.6

PEF_C5-GULFP 2267 E CLEARWATER230.00 TO 3834 ANCLOTE 230.00 CKT 1 637.0 974.2 150.2 728.0 1035.6 139.7

DB2269>2272>$1)(DB2267>3834>$1 2269 LK TARPON-A 230.00 TO 2280 GULF PINE 230.00 CKT 1 478.0

524.5 106.8

DB2288>3550>$1)(DB2269>2272>$1 2269 LK TARPON-A 230.00 TO 2280 GULF PINE 230.00 CKT 1 478.0 491.2 100.4

DB3834>3837>$1)(DB2267>3834>$1 2280 GULF PINE 230.00 TO 3834 ANCLOTE 230.00 CKT 1 1195.0 1264.6 103.6

PEF_C5-54 2735 CYPRESSWOOD 69.000 TO 2744 DUNDEE 69.000 CKT 1 149.0 163.8 108.0 177.3 118.3 10.3

PEF_C5-14 2780 LK WALES 69.000 TO 2834 W LAKE WALES69.000 CKT 1 149.0 150.9 101.5 161.4 108.9 7.4

PEF_C5-14 2780 LK WALES 69.000 TO 2834 W LAKE WALES69.000 CKT 2 149.0 158.3 104.4 166.1 112.0 7.6

PEF_C5-12 2881 FT MEADE 230.00 TO 2891 W LAKE WALES230.00 CKT 1 608.0 676.5 110.3 698.9 115.3 5.0

PEF_C2-10 3007 ALACHUA TAP 69.000 TO 3008 ALACHUA 69.000 CKT 1 36.0 35.8 94.9 37.7 100.1 5.2

PEF_C2-12 3007 ALACHUA TAP 69.000 TO 3008 ALACHUA 69.000 CKT 1 36.0 35.9 96.7 37.2 100.2 3.5

SG3163>3174>$1 3085 FT WHITE B 69.000 TO 3162 FT WHITE N 230.00 CKT 1 112.0 113.9 101.7 118.7 106.0 4.3 112.0 113.8 101.6 121.4 108.4 6.8

PEF_C2-146 3085 FT WHITE B 69.000 TO 3162 FT WHITE N 230.00 CKT 1 112.0 123.2 110.0 127.2 113.6 3.6 112.0 135.3 120.8 141.4 126.3 5.5

SG3003>3034>$1 3085 FT WHITE B 69.000 TO 3162 FT WHITE N 230.00 CKT 1

112.0 117.5 104.9 121.0 108.0 3.1


SG3003>3174>$1 3085 FT WHITE B 69.000 TO 3162 FT WHITE N 230.00 CKT 1 112.0 131.6 117.5 135.1 120.6 3.1

PEF_C5-4 3331 DALS AIRP TP69.000 TO 3334 DALLAS AIRPT69.000 CKT 1 74.0 78.7 105.9

PEF_C5-4 3331 DALS AIRP TP69.000 TO 3432 WILDWDCTY TP69.000 CKT 1 74.0 79.5 106.0

PEF_C5-4 3432 WILDWDCTY TP69.000 TO 6930 WILD W 69.000 CKT 1 79.0 85.5 105.8 96.2 119.1 13.3

PEF_C2-82 3432 WILDWDCTY TP69.000 TO 6930 WILD W 69.000 CKT 1 79.0 80.6 100.1 88.6 110.0 9.9

PEF_C5-4 3335 ANDERSEN 69.000 TO 6930 WILD W 69.000 CKT 1 75.0 91.5 117.6 102.4 131.5 13.9


SG3521>3525>$1 3335 ANDERSEN 69.000 TO 6930 WILD W 69.000 CKT 1 75.0 75.5 98.2 80.3 104.3 6.1



SG3551>3555>$1 3337 BUSHNELL E 69.000 TO 3365 CROOM TP 69.000 CKT 1 74.0 69.3 94.4 79.3 109.4 15.0

SG3551>3555>$1 3348 CONSOLIDRKTP69.000 TO 3350 BROOKSVILLE 69.000 CKT 1 75.0 73.4 96.0 84.0 110.8 14.8

SG3551>3555>$1 3348 CONSOLIDRKTP69.000 TO 3365 CROOM TP 69.000 CKT 1 75.0 72.9 96.0 83.3 110.7 14.7

PEF_C5-39 3385 INGLIS 69.000 TO 3469 INGLIS 115.00 CKT 1 112.0 115.2 102.8 121.5 108.5 5.7 112.0 121.0 108.0 130.6 116.6 8.6

DB3451>3477>$1)(DB3451>3474>$1 3387 INVERNESS 69.000 TO 3472 INVERNESS 115.00 CKT 2

60.0 65.1 108.5 67.5 112.5 4.0

DB3453>3474>$1)(DB3451>3477>$1 3387 INVERNESS 69.000 TO 3472 INVERNESS 115.00 CKT 2

60.0 59.4 99.1 61.9 103.2 4.1

DB3453>3477>$1)(DB3451>3474>$1 3387 INVERNESS 69.000 TO 3472 INVERNESS 115.00 CKT 2 60.0 62.0 103.3 64.5 107.4 4.1

PEF_C2-156 3393 LEESBURG E 69.000 TO 3395 LEESBURG 69.000 CKT 1 131.0 131.4 100.3 137.0 104.9 4.6

PEF_C2-85 3393 LEESBURG E 69.000 TO 3395 LEESBURG 69.000 CKT 1 131.0 125.4 95.3 133.6 101.8 6.5

SG2068>3521>$1 3393 LEESBURG E 69.000 TO 3395 LEESBURG 69.000 CKT 1 131.0 128.1 97.0 136.7 103.8 6.8

PEF_C5-3 3426 ROSS PRAIRIE69.000 TO 3435 MARIONOAKSTP69.000 CKT 1 138.0 147.4 106.3 159.3 115.1 8.8

SG3404>3434>$1 3426 ROSS PRAIRIE69.000 TO 3435 MARIONOAKSTP69.000 CKT 1 138.0 132.7 96.4 138.8 100.8 4.4

SG3426>3434>$1 3426 ROSS PRAIRIE69.000 TO 3435 MARIONOAKSTP69.000 CKT 1 138.0 132.7 96.4 138.8 100.8 4.4

PEF_C5-39 3445 LECANTO 115.00 TO 3532 LECANTO 230.00 CKT 1 336.0 326.0 97.0 352.8 105.0 8.0

DB3456>3523>$1)(DB3445>3532>$1 3450 BROOKRIDGE 115.00 TO 3452 HAMMOCK2 TP 115.00 CKT 1 134.0 148.9 110.9 165.6 123.2 12.3 178.0 189.5 106.7 212.5 119.7 13.0

DB3451>3519>$2)(DB3450>3518>$1 3450 BROOKRIDGE 115.00 TO 3518 BROOKRIDGE 230.00 CKT 2

280.0 279.8 99.9 285.7 102.0 2.1

DB3451>3519>$2)(DB3451>3519>$1 3450 BROOKRIDGE 115.00 TO 3518 BROOKRIDGE 230.00 CKT 2

280.0 321.7 114.9 330.4 118.0 3.1

DB3802>3807>$1)(DB3451>3519>$1 3450 BROOKRIDGE 115.00 TO 3518 BROOKRIDGE 230.00 CKT 2 280.0 270.4 96.6 282.5 100.9 4.3

DB3456>3523>$1)(DB3445>3532>$1 3452 HAMMOCK2 TP 115.00 TO 3463 HAMMOCK TP 115.00 CKT 1 128.0 139.5 109.3 156.1 122.2 12.9 175.0 182.1 104.9 204.9 118.1 13.2

PEF_C5-39 3456 CRYSTAL RV E115.00 TO 3523 CRYSTAL RV E230.00 CKT 1 280.0 291.9 104.2 300.0 107.2 3.0 280.0 310.8 111.0 323.6 115.6 4.6


DB3456>3523>$1)(DB3445>3532>$1 3463 HAMMOCK TP 115.00 TO 3478 TWIN CO RNCH115.00 CKT 1 134.0 130.7 99.8 146.7 112.2 12.4 178.0 171.5 99.7 193.5 112.6 12.9

SG3551>3555>$1 3518 BROOKRIDGE 230.00 TO 3WNDTR BROOKRIDGE WND 2 CKT 1 750.0 849.3 113.2 904.1 120.5 7.3

PEF_C2-160 3521 CENTRAL FLA 230.00 TO 3527 HOLDER 230.00 CKT 1 478.0

478.2 102.4

SG3551>3555>$1 3521 CENTRAL FLA 230.00 TO 3527 HOLDER 230.00 CKT 1 478.0 476.0 103.7

PEF_C5-40 3522 CRYST RVR PL230.00 TO 3526 KINGROAD PEF230.00 CKT 1 476.0 452.4 93.2 489.5 101.2 8.0

PEF_C2-158 3522 CRYST RVR PL230.00 TO 3527 HOLDER 230.00 CKT 1 656.0 648.5 98.7 692.1 105.6 6.9

SG3522>3527>$2 3522 CRYST RVR PL230.00 TO 3527 HOLDER 230.00 CKT 1 656.0 651.9 99.2 695.2 106.0 6.8

PEF_C2-163 3522 CRYST RVR PL230.00 TO 3527 HOLDER 230.00 CKT 2 656.0 648.5 98.7 692.1 105.6 6.9

SG3522>3527>$1 3522 CRYST RVR PL230.00 TO 3527 HOLDER 230.00 CKT 2 656.0 651.9 99.2 695.2 106.0 6.8

SG3551>3555>$1 3527 HOLDER 230.00 TO 3533 ROSS PRAIRIE230.00 CKT 1 656.0 594.4 92.5 653.3 102.9 10.4

SG3551>3555>$1 3550 BROOKRIDGE 500.00 TO 3WNDTR BROOKRIDGE WND 1 CKT 1 750.0 820.9 109.5 845.0 112.7 3.2 750.0 862.7 115.0 919.5 122.6 7.6

DB3670>3701>$1)(DB3483>3487>$1 3670 DISSTON 115.00 TO 3675 NORTHEAST 115.00 CKT 1

136.0

155.7 111.5

DB3701>3704>$1)(DB3483>3487>$1 3670 DISSTON 115.00 TO 3675 NORTHEAST 115.00 CKT 1 136.0 191.0 136.8

DB3703>3704>$6)(DB3483>3487>$1 3703 BARTOW 230.00 TO 3704 NORTHEAST 230.00 CKT 3

406.0

425.6 100.5


406.0

432.0 102.0

DB3703>3704>$8)(DB3483>3487>$1 3703 BARTOW 230.00 TO 3704 NORTHEAST 230.00 CKT 3 406.0 430.6 101.7


406.0

425.6 100.5


406.0

432.0 102.0

DB3703>3704>$8)(DB3483>3487>$1 3703 BARTOW 230.00 TO 3704 NORTHEAST 230.00 CKT 5 406.0 430.6 101.7

DB3810>3812>$1)(DB3806>3836>$1 3805 FLORAMAR 115.00 TO 3812 7 SPRINGS A 115.00 CKT 1 239.0 228.8 94.9 245.2 101.4 6.5

PEF_C5-28 3806 HUDSON A 115.00 TO 3836 HUDSON 230.00 CKT 1 280.0 269.8 96.4 280.7 100.3 3.9

PEF_C5-GULFP 3834 ANCLOTE 230.00 TO 3930 LARGO 230.00 CKT 1 637.0 670.7 100.9

DB2245>2268>$1)(DB2244>2267>$1 3910 TRI-CITY 115.00 TO 3911 ULMERTON 115.00 CKT 1 159.0 168.8 103.1 174.4 106.5 3.4

DB2268>2269>$1)(DB2244>2267>$1 3910 TRI-CITY 115.00 TO 3911 ULMERTON 115.00 CKT 1 159.0 168.8 103.1 174.4 106.5 3.4

DB3475>3802>$1)(DB3451>3519>$2 3451 BROOKSVL W 115.00 TO 3519 BROOKSVL W 230.00 CKT 1 280.0 268.9 96.0 289.7 103.5 7.5 280.0 316.3 113.0 339.6 121.3 8.3




DB3802>3807>$1)(DB3446>3482>$1 3451 BROOKSVL W 115.00 TO 3519 BROOKSVL W 230.00 CKT 1 280.0 265.6 94.9 283.2 101.2 6.3


Potential Third Part Impacts (To Be Evaluated Further by FRCC)

Summer STRESSED Dispatch Winter STRESSED Dispatch

ContingencyAlias Affected_Element Rating


MWPostCont


PercentOL


MWPostCont


PercentOL OL_Diff Rating


MWPostCont


PercentOL


MWPostCont


PercentOL OL_Diff

FMPA

PEF_C5-14 2883 INTERCSN CTY230.00 TO 5352 CAN ISL 230.00 CKT 1

776.0 849.8 108.0 980.2 128.5 20.5


776.0 752.1 94.8 885.3 114.8 20.0


776.0 805.6 102.0 937.6 122.3 20.3


776.0

833.0 107.4

FMPA_C5-3 2883 INTERCSN CTY230.00 TO 5352 CAN ISL 230.00 CKT 1 776.0 790.5 102.1

SECI

PEF_C5-3 3435 MARIONOAKSTP69.000 TO 6959 MARION TP 2 69.000 CKT 1 143.4 147.4 102.3 159.3 110.8 8.5

SG3359>3404>$1 6949 WATERWYS 69.000 TO 6960 MARION GOAB 69.000 CKT 1 70.8 70.4 99.0 73.9 104.1 5.1



PEF_C5-3 6950 SUMMRGLN 69.000 TO 6960 MARION GOAB 69.000 CKT 1 70.8 80.3 112.9 89.5 126.1 13.2

FP&L

FPL_C2-295 319 MYAKKA 138.00 TO 350 MYAKKA 230.00 CKT 1

224.0 233.6 104.3 240.8 107.5 3.2


224.0 233.6 104.3 240.8 107.5 3.2


224.0 233.6 104.3 240.8 107.5 3.2

SG331>337>$1 319 MYAKKA 138.00 TO 350 MYAKKA 230.00 CKT 1 224.0 233.7 104.3 240.8 107.5 3.2

FPL_C2-493 705 SYLVAN 230.00 TO 1703 YANKEE 230.00 CKT 1 588.0 704.4 116.6 734.8 122.3 5.7

FPL_C2-493 705 SYLVAN 230.00 TO 2585 N LONGWOOD 230.00 CKT 1 573.0 656.3 112.9 681.6 118.7 5.8

FPL_C2-493 742 SANFORDO 230.00 TO 1703 YANKEE 230.00 CKT 1 588.0 735.7 120.7 768.8 126.4 5.7

TECo

SG3774>3893>$1 3773 DENHAM 69.000 TO 8024 SUNLAKE 69.000 CKT 1 122.0 131.0 109.2 137.7 114.8 5.6 143.0 135.4 95.4 143.3 101.1 5.7



SG8402>8406>$1 3773 DENHAM 69.000 TO 8024 SUNLAKE 69.000 CKT 1

143.0 139.3 98.6 143.5 101.7 3.1

SG8406>8412>$1 3773 DENHAM 69.000 TO 8024 SUNLAKE 69.000 CKT 1 143.0 139.3 98.6 143.5 101.7 3.1


TEC_C2-70 8104 JACKSON RD S69.000 TO 8106 ROCKY CR 69.000 CKT 1 155.2 142.4 93.8 154.0 101.4 7.6

SG8400>8402>$1 8304 FERN T 69.000 TO 8382 JUNEAU-E 69.000 CKT 1 124.1 127.4 102.1 131.8 105.5 3.4 124.1 131.1 105.4 135.7 109.0 3.6

TEC_BPRO-22 8304 FERN T 69.000 TO 8382 JUNEAU-E 69.000 CKT 1 124.1 124.2 99.8 130.2 104.5 4.7 124.1 127.1 102.6 133.3 107.4 4.8

TEC_C2-9 8304 FERN T 69.000 TO 8382 JUNEAU-E 69.000 CKT 1 124.1 124.2 99.8 130.2 104.5 4.7 124.1 127.1 102.6 133.3 107.4 4.8

SG8018>8024>$1 8402 CHAPMAN 69.000 TO 8406 TPALM-NO 69.000 CKT 1 155.2 156.0 100.9 162.5 105.2 4.3

SG8018>8024>$1 8406 TPALM-NO 69.000 TO 8412 PEBBLECK 69.000 CKT 1 155.2 153.0 100.9 159.4 105.1 4.2

TEC_C2-70 8006 SHELDON-SE 69.000 TO 8106 ROCKY CR 69.000 CKT 1 155.2 173.2 112.1 185.6 120.1 8.0 155.2 178.5 116.2 190.2 123.8 7.6

DB8000>8100>$1)(DB8000>8050>$1 8000 SHELDON ROAD230.00 TO 8002 SHELDON-NW 69.000 CKT 1 224.0

229.9 102.6 224.0 208.4 93.0 231.2 103.2 10.2

DB8110>8370>$1)(DB8000>8100>$1 8000 SHELDON ROAD230.00 TO 8002 SHELDON-NW 69.000 CKT 1 224.0 225.8 100.8 224.0 206.6 92.2 229.5 102.5 10.3

TEC_C2-70 8000 SHELDON ROAD230.00 TO 8006 SHELDON-SE 69.000 CKT 1 196.0 193.1 98.5 214.0 109.2 10.7 196.0 196.8 100.4 216.4 110.4 10.0

SEC_C5-4 9000 POLKPLNT 230.00 TO 9050 PEBB 230.00 CKT 2 714.3 758.7 101.2 801.3 106.8 5.6 714.3 786.1 104.8 820.3 109.4 4.6

SG9000>9050>$2 9000 POLKPLNT 230.00 TO 9060 PEBBLDLE682 230.00 CKT 1 617.0 598.1 92.3 656.1 101.3 9.0

DB2269>8000>$3)(DB2269>8000>$2 2269 LK TARPON-A 230.00 TO 8070 WESTCHSE 230.00 CKT 1 656.0 878.1 130.7 717.0 762.1 103.8

DB2269>8070>$1)(DB2269>8000>$2 2269 LK TARPON-A 230.00 TO 8000 SHELDON ROAD230.00 CKT 3 656.0

874.6 129.9 729.4

754.3 101.4

DB8000>8070>$1)(DB2269>8000>$2 2269 LK TARPON-A 230.00 TO 8000 SHELDON ROAD230.00 CKT 3 656.0 854.1 126.8

DB2269>8000>$3)(DB2269>8000>$2 8000 SHELDON ROAD230.00 TO 8070 WESTCHSE 230.00 CKT 1 729.4 854.8 114.5

DB2269>8070>$1)(DB2269>8000>$3 2269 LK TARPON-A 230.00 TO 8000 SHELDON ROAD230.00 CKT 2 438.0 520.2 116.2 876.0 194.8 78.6 438.0 422.4 94.5 755.5 169.1 74.6

DB8000>8070>$1)(DB2269>8000>$3 2269 LK TARPON-A 230.00 TO 8000 SHELDON ROAD230.00 CKT 2 438.0 499.1 111.5 855.4 190.2 78.7 438.0

734.4 164.3

SG3551>3555>$1 2269 LK TARPON-A 230.00 TO 8000 SHELDON ROAD230.00 CKT 2 438.0

509.4 114.0 438.0

454.0 101.5


491.2 109.9


480.3 107.5


475.1 106.3


477.0 106.1


474.8 105.5


474.0 105.4


472.6 105.3


473.2 105.2


472.7 105.1


472.6 105.1


472.4 105.0


472.0 104.9



472.0 104.9


471.7 104.9


471.9 104.9


471.7 104.9


471.4 104.8


471.5 104.8


470.9 104.7


470.9 104.7


471.0 104.7


471.0 104.7


470.8 104.7


470.3 104.6


470.4 104.6


470.5 104.6


470.4 104.6


470.3 104.6


470.3 104.6


470.4 104.6


470.3 104.6


470.1 104.5


470.1 104.5


469.8 104.5


470.1 104.5


470.1 104.5


469.9 104.5


469.9 104.5


469.3 104.4


469.6 104.4


469.7 104.4


469.3 104.4


469.3 104.4


469.6 104.4


469.3 104.4



469.6 104.4


469.5 104.4


469.6 104.4


469.0 104.3


469.2 104.3


469.1 104.3


469.2 104.3


468.7 104.3


469.3 104.3


469.3 104.3


469.0 104.3


469.0 104.3


469.1 104.3


469.2 104.3


468.9 104.3


468.9 104.3


468.9 104.3


469.2 104.3


469.3 104.3


469.1 104.3


468.6 104.3


469.0 104.3


469.1 104.3


469.1 104.3


469.1 104.3


469.0 104.3


469.0 104.3


469.0 104.3


469.0 104.3


469.1 104.3


469.1 104.3


469.1 104.3


468.5 104.2



468.2 104.2


468.8 104.2


468.7 104.2


468.6 104.2


468.9 104.2


468.5 104.2


468.5 104.2

DB3663>3675>$A)(DB2269>8070>$1 2269 LK TARPON-A 230.00 TO 8000 SHELDON ROAD230.00 CKT 2 438.0

468.9 104.2

DB3663>3675>$B)(DB2269>8070>$1 2269 LK TARPON-A 230.00 TO 8000 SHELDON ROAD230.00 CKT 2 438.0

468.9 104.2


468.8 104.2


468.8 104.2


468.9 104.2


468.7 104.2


468.9 104.2

DB3683>3702>$1)(DB2269>8070>$1 2269 LK TARPON-A 230.00 TO 8000 SHELDON ROAD230.00 CKT 2 438.0 468.7 104.2


Appendix B

Anclote Phase I Repowering Short Circuit Results

BASE 1RP

BUS

# BUS NAME

3PH

AMP

SLG

AMP

3PH

AMP

SLG

AMP

%

3PH

%

SLG Comments # kV

2221 E CLEARWATER 69 32875.3 28122.2 33460.6 28603.4 1.8% 1.7% 26,000 A Replace 39 & 711 with 50,000 A breakers 2 69

2242 BAYVIEW 115 26197.2 19100.2 26797.6 19399.9 2.3% 1.6% 22,000 A Replace 1125, 1127, 1129 with 40,000 A breakers 3 115

2267 E CLEARWATER 230 27299.5 22289.3 29071.7 23697.3 6.5% 6.3% 20,000 A Replace 1470 & 1472 with 50,000 A breakers 2 230

2269 LK TARPON-A 230 40688.4 34086.1 44332.8 36967.7 9.0% 8.5% 40,000 A Replace 1864, 2969, 2970, 4548 with 63,000 A breakers 4 230

3645 DISSTON 69 25832 15386.2 26098.2 15467 1.0% 0.5% 27,000 A Replace 109, 123, 748 with 40,000 A breakers 3 69

3669 CROSSROADS 115 23953.5 18818 24311.5 18995.7 1.5% 0.9% 22,000 A Replace 1390 with 40,000 A breaker 1 115

3670 DISSTON 115 30743 28901.8 31327.3 29289.3 1.9% 1.3% 22,000 A Replace 4 & 141 with 40,000 A breakers 2 115

3672 GATEWAY 115 25479.3 17942.7 25968.3 18137.2 1.9% 1.1% 22,000 A Replace 4492 with 40,000 A breaker 1 115

3673 KENNETH CTY 115 23534.3 18032.5 23878.3 18192.6 1.5% 0.9% 25,000 A Replace 1621 with 40,000 A breaker 1 115

3804 ELFERS 115 20686.1 14427.3 22264.7 15893.7 7.6% 10.2% 22,000 A Replace 1525, 1527, 1561 with 40,000 A breakers 3 115

3812 7 SPRINGS A 115 33066.8 25457.2 37300.7 30435.2 12.8% 19.6% 22,000 A Replace 2720 with 50,000 A breaker 1 115

3815 TARPON SPNGS 115 23633.2 18700.3 24875.1 20304.5 5.3% 8.6% 20,000 A Replace 62, 84, 316, 4273 with 50,000 A breakers 4 115

3834 ANCLOTE 230 26464.5 26924.7 38461.7 42668.9 45.3% 58.5% Install 63,000 A breakers 18 230

3837 7 SPRINGS 230 25403.8 17041.7 34799.8 24241.8 37.0% 42.2% 20,000 A Replace 2734 & 2736 with 63,000 A breakers 2 230

3882 LARGO A 69 35267.7 29905 35925.8 30426.7 1.9% 1.7% 40,000 A Replace all 13 breakers with 63,000 A breakers 13 69

3911 ULMERTON 115 31466.5 27848.5 32276.4 28414 2.6% 2.0% 10,000 A Replace 26, 37, 936 with 50,000 A breakers 3 115

3932 ULMERTON 230 30862.4 28968.6 32339.9 30096.2 4.8% 3.9% 15,000 A Replace 964 with 63,000 A breaker 1 230

2280 GULF PINE 230

38770.9 27275.4

Install 63,000 A breakers (incuded in GULF estimate)

3476 TANGERINE 115 15578.7 9309.9 17270.8 9320.6 10.9% 0.1% OK 25,000 A Ckt Switcher

3484 HERNANDO AIR 115 10836.7 6130.5 11079.7 6197.9 2.2% 1.1% OK 25,000 A Ckt Switcher

3486 PINE RIDGE 115 14248.9 9407.3 14641.1 9522.7 2.8% 1.2% OK 25,000 A Ckt Switcher

3811 PASCO RR 115 22151.1 16425.4 23235.2 16970.6 4.9% 3.3% 3RD PARTY

3839 SHADY HILLS 230 18543.8 13513.2 20668.6 14650.6 11.5% 8.4% 3RD PARTY

7077 NP RICHY 115 17694.6 10988.6 18318.8 11400.1 3.5% 3.7% 3RD PARTY

7105 PSCOT TP 115 22206.9 15958.5 23288.6 16480.5 4.9% 3.3% 3RD PARTY

7110 RIDGE 115 16988.8 10485.2 17561.5 10858.2 3.4% 3.6% 3RD PARTY


8000 SHELDON ROAD 230 36769.5 28569 38934.7 29921.3 5.9% 4.7% 3RD PARTY

8070 WESTCHSE 230 32636.5 24443.5 34652.6 25686.6 6.2% 5.1% 3RD PARTY

Breaker count by voltage class

69 kV 18

115 kV 19

230 kV 27

SYSTEM IMPACT STUDY FOR THE ANCLOTE REPOWERING PROJECT – PHASE I TRANSIENT STABILITY REPORT VOLUME 1 OCTOBER – 2012 Principal Contributor FABIO RODRIGUEZ, P.E.

THIS DOCUMENT AND ANY ATTACHMENTS HERETO ("DOCUMENT") IS MADE AVAILABLE BY PROGRESS ENERGY COMPANY UPON AND SUBJECT TO THE EXPRESS UNDERSTANDING THAT: (A) NEITHER PROGRESS ENERGY COMPANY NOR ANY OF ITS OFFICERS, DIRECTORS, AFFILIATES, AGENTS, OR EMPLOYEES MAKES ANY WARRANTY, ASSURANCE, GUARANTY, OR REPRESENTATION WITH RESPECT TO THE CONTENTS OF THE DOCUMENT OR THE ACCURACY OR COMPLETENESS OF THE INFORMATION CONTAINED OR REFERENCED IN THE DOCUMENT, AND (B) PROGRESS ENERGY COMPANY, ITS OFFICERS, DIRECTORS, AFFILIATES, AGENTS, AND EMPLOYEES SHALL NOT HAVE ANY LIABILITY OR RESPONSIBILITY FOR INACCURACIES, ERRORS, OR OMISSIONS IN, OR ANY BUSINESS OR POLICY DECISIONS MADE BY ANY DIRECT OR INDIRECT RECIPIENT IN RELIANCE ON, THIS DOCUMENT OR THE INFORMATION CONTAINED OR REFERENCED THEREIN; ALL SUCH LIABILITY IS EXPRESSLY DISCLAIMED."

OCTOBER 2012. SIS ANCLOTE PHASE I PROJECT TRANSIENT STABILITY REPORT i

Executive Summary The proposed Progress Energy Anclote-Phase I Repowering Plant (“Project”) consists of a combined cycle power plant composed of three new combustion turbines and the existing Anclote 1 steam unit. The winter gross output of the combined cycle Anclote-Phase I plant is 1329 MW, 0.90 PF. The Project will interconnect to the Progress Energy Florida 230 kV system at the existing Anclote substation in Pasco County, Florida. The current proposed in service date for the Project is summer 2016. The results of the transient stability analysis indicate that the addition of the Project, its associated reinforcements and required transmission system upgrades will have no significant impact on the transient stability response of the bulk transmission system. The interconnection of the proposed Project will include new transmission facilities and the upgrade of several existing transmission facilities identified in the steady state and short circuit studies. The following are the transmission facilities identified in the transient stability study directly related to the interconnection of the Project:

• Upgrade and/or improvement of protection systems and associated clearing times at the following 230 kV and 115 kV transmission facilities: Gulf Pine 230 kV Anclote 230 kV Seven Springs 230 kV and 115 kV Hudson 230 kV and 115 kV East Clearwater 230 and 115 kV

• Installation of Out of Step Protection relays (OOS) on each Anclote generating unit. • Installation of Power System Stabilizers (PSS) on each Anclote CT generating unit.

The gross cost estimate for the above upgrades is $9 Million. Upgrades and/or improvements of protection systems and associated clearing times should be implemented at the Lake Tarpon 500 kV and 230 kV, Largo 230 kV, and Palm Harbor 230 kV for which the Project is not responsible. These upgrades should be done as part of Progress Energy regular transmission planning process. All relevant plants and firm transactions ahead of the Project in the FRCC combined Long-Term Firm Transmission and Generation Interconnection Service Requests Queue were modeled in this study. The steady state and short circuit analyses are provided in a separate report. Any changes or modifications to the present proposal for the Project will require additional study work to identify new impacts to the transmission system.

OCTOBER 2012. SIS ANCLOTE PHASE I PROJECT TRANSIENT STABILITY REPORT ii

Table of Contents

EXECUTIVE SUMMARY ............................................................................................................................................... I

TABLE OF CONTENTS ................................................................................................................................................ II

LIST OF FIGURES AND TABLES .............................................................................................................................. III

1.0 INTRODUCTION ................................................................................................................................................ 1

2.0 INTERCONNECTION FACILITIES ................................................................................................................ 1

3.0 SYSTEM REPRESENTATION .......................................................................................................................... 2

3.1 BASE CASE LOAD FLOWS ..................................................................................................................................... 2 3.2 DYNAMIC MODELING .......................................................................................................................................... 2 3.3 SYSTEM REINFORCEMENTS ASSOCIATED WITH THE ANCLOTE-PHASE I PROJECT ................................................ 3

4.0 TRANSIENT STABILITY ANALYSIS METHODOLOGY ............................................................................ 6

4.1 NORMAL CONTINGENCY ASSESSMENT ................................................................................................................ 6 4.2 EXTREME CONTINGENCY ASSESSMENT ............................................................................................................... 7 4.3 EVALUATION OF SYSTEM RESPONSE TO NORMAL AND EXTREME CONTINGENCIES ........................................... 10

5.0 DISCUSSION OF STUDY RESULTS .............................................................................................................. 10

5.1 ASSESSMENT OF NERC CATEGORIES B AND C CONTINGENCIES ....................................................................... 11 5.2 ASSESSMENT OF NERC CATEGORY D CONTINGENCIES .................................................................................... 14

6.0 CONCLUSIONS AND RECOMMENDATIONS ............................................................................................ 16

APPENDIX I LOADFLOW SUMMARIES ............................................................................................................... I-1

APPENDIX II PLANT AND ADDITIONAL MODELS......................................................................................... II-1

APPENDIX III CONTINGENCY MODEL DESCRIPTIONS ............................................................................ III-1

III-1 CONTINGENCY DESCRIPTION ............................................................................................................................... 2 III-2 SHUNT ADMITANCE ............................................................................................................................................. 5

APPENDIX IV TRANSIENT STABILITY RESULT PLOTS ............................................................................. IV-1

OCTOBER 2012. SIS ANCLOTE PHASE I PROJECT TRANSIENT STABILITY REPORT iii

List of Figures and Tables FIGURE 2.1 PROPOSED INTERCONNECTION OF THE PROJECT ............................................................................................... 1 FIGURE 3.3.1 GULF PINE 230 KV SUBSTATION .................................................................................................................... 3 FIGURE 3.3.2 ONE LINE DIAGRAM OF LOCAL AREA ............................................................................................................ 5 TABLE 3.1.1 DISPATCH OF RELEVANT PLANTS ................................................................................................................... 2 TABLE 3.3.1 BULK POWER SYSTEM UPGRADES RELATED TO THE PROJECT ........................................................................ 4 TABLE 4.1.1 NORMAL CONTINGENCIES ............................................................................................................................... 7 TABLE 4.1.2 EXTREME CONTINGENCIES .............................................................................................................................. 8 TABLE 5.1.1 CATEGORIES B, C AND D RESULTS............................................................................................................... 11

OCTOBER 2012. SIS ANCLOTE PHASE I PROJECT TRANSIENT STABILITY REPORT 1

1.0 Introduction Progress Energy Florida is proposing the construction of a combined cycle power plant with a total winter gross output of 1329 MW, 0.90 PF (“Project”). The proposed Anclote combined cycle plant consists of three new combustion turbines and the existing Anclote 1 steam turbine, the maximum gross output of each combustion unit is 297 MW with a station service load of 35 MW, 0.80 PF. The Project will interconnect to the Progress Energy Florida 230 kV system at the existing Anclote substation in Pasco County, Florida. The current proposed in service date for Project is summer 2016. This Generation Interconnection System Impact Study evaluated transient stability system performance. Steady state and short circuit system studies are available in a separate report. The impact of other relevant proposed generation projects in the study area was considered in this study. Analysis for the Project and its impact on the Florida bulk transmission system was performed in accordance with, FERC Large Generation Interconnection Rules, NERC/FRCC Reliability Standards, and Progress Energy Florida Interconnection Requirements.

2.0 Interconnection Facilities The proposed interconnection of the Project to the PEF bulk transmission system will be through the construction of two bays at the existing Anclote 230 kV substation. The 230 kV yard will be upgraded to five breaker-and-a-half bays. Figure 2.1 shows the one line diagram for the proposed interconnection.

Figure 2.1 Proposed Interconnection of the Project


3.0 System Representation The following sections describe in detail the system representation used in the transient stability.

3.1 Base Case Load flows Stability cases were developed with the 2010 Revision 4 FRCC dynamic library. 2015 summer peak load (100%) and light load (50%) cases were used in this study.

The FRCC system peak load plus losses was 48832 MW and the light load plus losses was 24387 MW. The peak and light load base cases maximized available generation in the study area and modeled the Southern-Florida interface at 3700 MW. The total Project output is modeled at a winter gross output of 1329 MW with a 35 MVA station service load with a 0.80 PF. Table 3.1.1 shows the dispatch of major units in the study area.

Table 3.1.1 Dispatch of Relevant Plants

PK-1 (MW)

LL-1 (MW)

LL-2 (MW)

Anclote Combine Cycle 1329 1329 1329

Crystal River Complex 500 kV 1800 1080 1080

Crystal River Complex 230 kV 1590 722 1216

Anclote Unit 2 510 510 510

Shady Hills 486 486 486

Higgins 110 110 110

Bayboro 172 0 0

Bartow 1133 0 179

SOCO-FLA Interface 3700 3700 3700

A detailed summary of generation dispatch, interface transfers, and voltage conditions is included in Appendix I for each of the load flows listed in Table 3.1.1. 3.2 Dynamic Modeling The dynamic model for this study was taken from the 2010 FRCC SWG library. Additional models were added to the snapshot as required to model the proposed Anclote-Phase I


generating plant, and to model additional protective relays where required. Data for the Anclote-Phase I units and additional protective relay models are listed in Appendix II. For the Anclote-Phase I combustion units, the generators are modeled using PSS/E model GENROU, the excitation systems are modeled as IEEE type ST6B excitation system using PSS/E model ST6B, the power system stabilizers are modeled as IEEE Dual-Input using PSS/E model PSS2B and the governors are modeled using the SIEMENS user model USGT8H. The analysis documented in this report is based on the Anclote CT generating units power system stabilizers activated. Some delayed fault clearing contingencies caused the Anclote-Phase I units to lose synchronism with the system. Out of step relays might be modeled for each Anclote-Phase I generating unit with PSS/E model SLINOS. The blinder type relay characteristic could be used and may be obtained with an ABB type RXZK 23 H impedance relay. A similar characteristic may be available with relays available from other manufactures. The analysis documented in this report did not specifically simulate the out of step relay, instead a generic FLEX code model was used to trip units for either a preset angle or speed deviation. This study includes detailed models of the out of step special protection systems (SPS) and automatic under frequency load shedding schemes as specified by the FRCC SWG.

3.3 System Reinforcements Associated with the Anclote-Phase I Project The upgrades associated with the Project include steady state, short circuit and stability related upgrades as they relate to the bulk power system. Figures 3.3.1 and 3.3.2 show the one line diagram of the proposed new 230 kV Gulf Pine substation and the one line diagram of the local area, respectively. Table 3.5.1 lists the bulk power system upgrades identified in the steady state analysis that were included in this study.

Figure 3.3.1 Gulf Pine 230 kV Substation


Table 3.3.1 Bulk Power System Upgrades Related to the Project

1. Anclote 230 kV Substation. Addition of two three-and-a-half breaker bays

2. New Gulf Pine 230 kV Substation. Four three-and-a-half breaker bays

3. Loop 230 kV line Seven Springs – Brookridge into Gulf Pine substation

4. Loop 230 kV line Seven Springs – Lake Tarpon into Gulf Pine Substation 5. New Anclote – Gulf Pine 230 kV line with 2-bundle 795 ACSS 6. Reconductor the Anclote – Seven Springs 230 kV line with 2-bundle 795 ACSS

7. Upgrade terminal equipment at the Seven Springs 230 kV substation to 3000 A

8. Reconductor the Brookridge – Crystal River South 115 kV line with 1622 ACSS/TW

9. Reconductor the Spring Hill – Heritage Tap 115 kV line with 1622 ACSS/TW

10. Upgrade the Brookridge 112 MVA transformer to 280 MVA 11. Replace limiting elements at East Clearwater to get full rating of 230/115 kV transformer 12. Replace limiting elements at Gulf Pine – Hudson 230 kV line

13. Replace limiting elements at Gulf Pine – Lake Tarpon 230 kV line

14. Replace limiting elements at Lake Tarpon – Sheldon Rd 230 kV line

15. Install 2x25 capacitor bank at Brookridge 115 kV substation

16. Add Brooksville/ Brooksville West expansion project


7 SPRINGS230.kV

7 SPRINGS115.kV

ANCLOTE230.kV

ANCL COOL230.kV

ANCLOTE G222.kV

ANCL-STA22.kV

BKVW230.kV

BROOKRIDGE230.kV

CURLEW230.kV

E CLEARWATER230.kV

HUDSON230.kV

LARGO230.kV

LAKE TARPON230.kV

SHADY HILLS230.kV

SHADY HLS P118.kV

SHADY HLS P218.kV

SHADY HLS P318.kV

ULMERTON230.kV

GULF PINE230.kV

BKVL230.kV

BKVL115.kV BKVW

115.kV

ANCL-CTA119.kV

ANCL-CTA219.kV

ANCL-CTA319.kV

Figure 3.3.2 One Line Diagram of Local Area


4.0 Transient Stability Analysis Methodology This study was conducted based on FERC Large Generation Interconnection Rules, NERC/FRCC Reliability Standards, and Progress Energy Florida Interconnection Requirements. Normal and extreme criteria contingencies were tested and evaluated for cases with the Project on line and off line when necessary. These tests were conducted at 50% of peak and peak load levels which are the typical load levels at which FRCC performs stability studies1. For both load levels as many generators as possible were turned on in the study area. Stability results were analyzed using the criteria in the NERC Reliability Standards and in the Transmission Planning Guide for the Progress Energy Company. Normally cleared Three Phase fault and Single Line to Ground fault with breaker failure contingencies were simulated in accordance with NERC Categories B and C criteria, respectively. In cases where two independent protection groups exist on a facility, the contingency was modeled assuming the correct operation of the faster protection group. All extreme contingencies, involving breaker failure, were simulated in accordance with NERC Category D criteria assuming correct operation of all protection groups. All extreme contingencies, involving relay system or signal malfunction, were simulated in accordance with NERC Category D criteria. In cases where two independent protection groups exist on a facility, the contingency was modeled assuming the operation of the slowest protection group. In cases where only one protection group exists on a facility, the fault clearing was initiated from the remote line terminals, resulting in isolation of additional system elements beyond the faulted element.

4.1 Normal Contingency Assessment The normal contingency assessment involved the simulation of the following type of faults: • “Permanent 3 phase fault on any generator, transmissions circuit, transformer or bus

section, with normal fault clearing.” • “A permanent phase-to-ground fault on any transmission circuit, transformer or bus

section with delayed fault clearing. This delayed fault clearing could be due to circuit breaker, relay system or signal channel malfunction.”

• “A permanent 3 phase fault on any circuit off a double circuit tower - DCT.” • Permanent phase-to-ground faults with delayed fault clearing were tested if for the

corresponding 3-phase faults with delayed clearing exhibited unstable response. The following permanent 3-phase normally cleared faults and SLG delay cleared faults were tested; a detailed description of each contingency2 is included in Appendix III-1:

1 See FRCC Dynamic Simulation Studies and Impact of System Demand Levels Report published by the SWG. 2 The naming of the contingency includes a four digit letter of the substation name or a three digit name and a number (to indicate voltage level) followed by a three digit number indicating the type of fault; the one hundred series indicates


Table 4.1.1 Normal Contingencies

NFLT: A no fault steady state no disturbance response ANCL101 3- ph fault at Anclote on Anclote-Seven Springs 230 kV line ANCL102 3- ph fault at Anclote on Anclote-Gulf Pine 230 kV line ANCL103 3- ph fault at Anclote on Anclote East Clearwater 230 kV line ANCL200 SLG fault at Anclote 230 kV NBKR4 BF ECL1209 SLG fault at E Clearwater 115 kV bus. Delay clearing from remote ends ECLW200 SLG fault at E Clearwater 230 kV 1470 BF. ADJ-DTT ECLW209 SLG fault at E Clearwater 230 kV bus. Delay clearing from remote ends GULF101 3-ph fault at Gulf Pine on Gulf Pine-Anclote 230kV line GULF102 3- ph fault at Gulf Pine on Gulf Pine-Hudson 230 kV line GULF103 3- ph fault at Gulf Pine on Gulf Pine-Lake Tarpon A 230 kV line GULF201 3- ph fault at Gulf Pine on Gulf Pine-Lake Tarpon 230 kV DCT LRGO101 3- ph fault at Largo on Largo-Anclote 230 kV line LRGO200 SLG fault at Largo 230 kV 3130 BF LRGO209 SLG fault at Largo 230 kV bus. Delay clearing from remote ends HUDS101 3- ph fault at Hudson on Hudson-Gulf Pine 230 kV line HUDS201 SLG fault at Hudson 230 kV 2515 BF LTP2101 3- ph fault at Lake Tarpon on Lake TarponB-Gulf Pine 230 kV line LTP2102 3-ph fault at Lake Tarpon on Lake Tarpon -Sheldon-TECO 230 kV line LTP2103 3-ph fault at Lake Tarpon on Lake Tarpon -Sheldon-TECO 230 kV DCT?? LTP2200 SLG fault at Lake Tarpon 230 kV 4549 BF LTP2209 SLG fault at Lake Tarpon 230 kV bus. Delay clearing from remote ends LTPN101 3-ph fault at Lake Tarpon on Lake Tarpon-Brookridge 500 kV PMHR209 SLG fault at Palm Harbor 230 kV bus. Delay clearing from remote ends SEV1101 3- ph fault at Seven Springs on Seven Springs-Port Richie 115 kV line SEV1102 3- ph fault at Seven Spring on Seven Springs-Floramar 115 kV line SEV1209 SLG fault at Seven Springs 115 kV bus. Delay clearing from remote ends SEVS101 3-ph fault at Seven Springs on Seven Springs-Anclote 230 kV line SEVS201 SLG fault at Seven Springs 230 kV 2738 BF. ADJ-DTT SEVS209 SLG fault at Seven Springs 230 KV bus. Delay clearing from remote ends SHEL101 3-ph fault at Sheldon on Sheldon-Juneau 230 kV line (TECO) SHEL201 SLG fault at Sheldon 230 kV 0000 BF (TECO) SHEL209 SLG fault at Sheldon 230 kV bus. Delay clearing from remote ends. Z3 (TECO)

4.2 Extreme Contingency Assessment The extreme contingency assessment included the simulation of the following type of faults: • “Permanent 3-phase fault on any generator, transmission circuit, transformer or bus

section, with delayed fault clearing and with due regard to reclosing. This delayed fault clearing could be due to circuit breaker, relay system or signal channel malfunction.”

a 3-phase normal cleared fault, the two hundred series indicates a SLG fault with stuck breaker or a LLG fault with normal clearing and the ten series indicates the number of the contingency within the substation.


• “Loss of all transmission lines on a common right-of-way.” • “Loss of all generating units at a station.” • “Loss of a substation (one voltage level plus transformers).” Permanent 3-phase faults with breaker failure and 3-phase faults with relay failure were tested; a detailed description of each contingency3 is included inAppendix III-1:

Table 4.1.2 Extreme Contingencies

ALDM309 3-ph fault at Alderman 115 kV bus. Delay clearing from remote ends ANCL300 3-ph fault at Anclote 230 kV NBKR4 BF ANCL301L 3-ph fault at Anclote 230 kV 4352 BF. ADJ-Z2 ANCL301 3-ph fault at Anclote 230 kV 4352 BF. ADJ-DTT ANCL302 3-ph fault at Anclote on Anclote-Seven Springs 230 kV line RF ANCL303 3-ph fault at Anclote on Anclote-Largo 230 kV line RF ANCL309 3-ph fault at Anclote 230 kV bus. Delay clearing from remote ends BKR1301 3-PH fault at Brookridge 115 kV 3644 BF BKR2301 3-ph-fault at Brookridge 230 kV 4921 BF BKRG301 3-ph fault at Brookridge 500 kV 5132 BF BKV1303 3-ph fault at Brooksville West 115 kV B1119 BF BKVW301 3-ph fault at Brooksville West 230 kV B1105 BF CFL2301 3-ph fault at Central Florida 230 kV 1914 BF CFLA301 3-ph fault at Central Florida 500 kV 5114 BF CIT2301 3-ph fault at Citrus 230 kV 2227 BF CRP5302 3-ph fault at Crystal River 500 kV 1662 BF CRPL301 3-ph fault at Crystal River 230 kV 3234 BF CURL309 3-ph fault at 115 kV Curlew bus. Delay clearing from remote ends ECL1309 3-ph fault at E Clearwater 115 kV bus. Delay clearing from remote ends ECLW300L 3-ph fault at E Clearwater 230 kV 1470 BF. ADJ-Z2 ECLW300 3-ph fault at E Clearwater 230 kV 1470 BF. ADJ-DTT ECLW301 3-ph fault at E Clearwater 230 kV 1472 BF ECLW302 3-ph fault at E Clearwater 230 kV 1478 BF ECLW303 3-ph fault at E Clearwater on E Clearwater-Ulmerton 230 kV line RF ECLW309 3-ph fault at E Clearwater 230 kV bus. Delay clearing from remote ends ELFR309 3-ph fault at Elfers 115 kV bus. Delay clearing from remote ends FLMR309 3-ph fault at Floramar 115 kV bus. Delay clearing from remote ends GULF300 3-ph fault at Gulf Pine 230 kV N4 BF GULF301L 3-ph fault at Gulf Pine 230 kV N3 BF. ADJ-Z2 GULF301 3-ph fault at Gulf Pine 230 kV N3 BF. ADJ-DTT GULF302 3-ph fault at Gulf Pine 230 kV N1 BF GULF303 3-ph fault at Gulf Pine on Gulf Pine-Seven Springs 230 kV line RF GULF304 3-ph fault at Gulf Pine on Gulf Pine-Brooksville West 230 kV line RF

3 The naming of the contingency includes a four digit letter of the substation name or a three digit name and a number (to indicate voltage level) followed by a three digit number indicating the type of fault; the three hundred series indicates a 3-phase fault with delay clearing, a loss of R/W, or a loss of Substation and the ten series indicates the number of the contingency within the substation.


GULF309 3-ph fault at Gulf Pine bus. Delay clearing from remote ends HOLD303 3-ph fault at Holder 230 kV 2624 BF HUD1300 3-ph fault at Hudson 115 kV 6648 BF HUD1301 3-ph fault at Hudson 115 kV 2636 BF HUD1302 3-ph fault at Hudson 115 kV 2635 BF HUD1309 3-ph fault at Hudson 115 kV bus. Delay clearing from remote ends HUDS300 3-ph fault at Hudson 230 kV 2519 BF HUDS301 3-ph fault at Hudson 230 kV 2515 BF HUDS302 3-ph fault at Hudson 230 kV 2516 BF HUDS303 3-ph fault at Hudson on Hudson-Shady Hills 230 kV line RF HUDS304 3-ph fault at Hudson on Hudson-Brookridge 230 kV line RF HUDS304N 3-ph fault at Hudson on Hudson-Gulf Pine 230 kV line RF HUDS309 3-ph fault at Hudson 230 kV bus. Delay clearing from the remote ends LRGO300 3-ph fault at Largo 230 kV 3130 BF LRGO301 3-ph fault at Largo 230 kV 3134 BF LRGO303 3-ph fault at Largo on Largo-Ulmerton 230 kV line RF LRGO309 3-ph fault at Largo 230 kV bus. Delay clearing from the remote ends LTP2300 3-ph fault at Lake Tarpon 230 kV 4549 BF LTP2300A 3-ph fault at Lake Tarpon 230 kV 4549 BF LTP2301 3-ph fault at Lake Tarpon 230 kV 1861 BF LTP2302 3-ph fault at Lake Tarpon 230 kV 1858 BF LTP2304 3-ph fault at Lake Tarpon on Lake Tarpon-Sheldon 230 kV line RF LTP2305 3-ph fault at Lake Tarpon on Lake Tarpon-Higgins 230 kV line RF LTP2309 3-ph fault at Lake Tarpon 230 kV bus. Delay clearing from remote ends LTPN301 3-ph fault at Lake Tarpon 500 kV 4619 BF LTPN309 3-ph fault at Lake Tarpon 500 kV bus. Delay clearing from remote ends NWPR309 3-ph fault at New West Port Richie 115 kV bus. Delay clearing from remote ends PMHR309 3-ph fault at Palm Harbor 230 kV bus. Delay clearing from the remote ends SEV1300 3-ph fault at Seven Springs 115 kV 4680 BF SEV1301L 3-ph fault at Seven Springs 115 kV 2722 BF. ADJ-Z2 SEV1301 3-ph fault at Seven Springs 115 kV 2722 BF. ADJ-DTT SEV1302 3-ph fault at Seven Springs 115 kV 2012 BF SEV1303 3-ph fault at Seven Springs on Seven Springs-Floramar 115 kV line RF SEV1309 3-ph fault at Seven Springs 115 kV bus. Delay clearing from remote ends SEVS300 3-ph fault at Seven Springs 230 kV 2005 BF SEVS301L 3-ph fault at Seven Springs 230 kV 2738 BF. ADJ-Z2 SEVS301 3-ph fault at Seven Springs 230 kV 2738 BF. ADJ-DTT SEVS302 3-ph fault at Seven Springs on Seven Springs-Gulf Pine 230 kV line RF SEVS303 3-ph fault at Seven Springs on Seven Springs-Anclote 230 kV line RF SEVS309 3-ph fault at Seven Springs 230 kV bus. Delay clearing from the remote ends SHEL301 3-ph fault at Sheldon 230 kV 0000 BF (TECO) SHEL301A 3-ph fault at Sheldon 230 kV 0000 BF (TECO) SHEL304 3-ph fault at Sheldon on Sheldon-Lake Tarpon 230 kV line RF (TECO) SHEL309 3-ph fault at Sheldon 230 kV bus. Delay clearing from remote ends. Z3 (TECO) TPNS309 3-ph fault at Tarpon Springs 115 kV bus. Delay clearing from remote ends ULMR303 3-ph fault at Ulmerton on Ulmerton-East Clearwater 230 kV line RF ULMR304 3-ph fault at Ulmerton on Ulmerton-Largo 230 kV line RF


ANCL310 Loss of Anclote 230 kV substation ANCL311 Loss of all generating units at the Anclote Plant CRPL310 Loss of all generating units at the Crystal River Plant LROW301 Loss of Right-Of-Way East of Anclote LROW302 Loss of Right-Of-Way South of Crystal River LROW303 Loss of Right-Of-Way South of Brookridge LROW304 Loss of Right-Of-Way North of Lake Tarpon

4.3 Evaluation of System Response to Normal and Extreme Contingencies System Response to a Category B Contingency. The following responses are considered an unacceptable system response to a category B contingency: • Transiently unstable response resulting in wide spread system collapse. • Transiently stable response with undamped power system oscillations. • Activation of any under frequency load shedding scheme. • A voltage variation greater than +-20% from steady state and a voltage below 0.90 pu

after 1 second of fault inception on the high side terminals of the transformers that feed the reserve auxiliary equipment for the Crystal River 3 nuclear unit.

System Response to a Category C Contingency. The following responses are considered an unacceptable system response to a category C contingency: • Transiently unstable response resulting in wide spread system collapse. • Transiently stable response with undamped power system oscillations. • A voltage variation greater than +-20% from steady state and a voltage below 0.90 pu

after 1 second of fault inception on the high side terminals of the transformers that feed the reserve auxiliary equipment for the Crystal River 3 nuclear unit.

System Response to a Category D Contingency4. The following responses are considered an unacceptable system response to an extreme contingency: • Transiently unstable response resulting in wide spread system collapse. • Transiently stable response with undamped or sustained power system oscillations. • A voltage below 0.80 pu for more than 0.75 seconds and a voltage below 0.95 pu after 5

seconds of fault inception on the high side of the transformers that feed the reserve auxiliary equipment for the Crystal River 3 nuclear unit.

5.0 Discussion of Study Results Simulations of the contingencies listed in Section 4 for the system described in Section 3 are discussed in detail in this section. Generally, a more onerous system response to contingency events was observed for the light load cases. Transient stability output plots are provided in Appendix IV, which is published in a separate volume and available upon request.

4 This criterium is specific only to Category D1, D2, D3 and D4 Contingencies.


5.1 Assessment of NERC Categories B and C Contingencies Table 5.1.1 summarizes the contingency results for NERC Categories B and C contingencies with the Project interconnecting to the system at the Anclote 230 kV substation. Detail on each load flow case is provided in Appendix I, contingency switching modeling is provided inAppendix III-1, and transient stability output plots in Appendix IV. Three phase normally cleared faults assuming the correct operation of the faster protective relay group and single-line-to-ground faults accompanied by circuit breaker failure were simulated at Anclote and other area substations as listed in Section 4. For all Category B contingencies tested, a stable damped system response was observed. The results of the study showed system violations for Category C contingencies at various substations in the local area. It is proposed to install independent redundant high speed protection systems at the following substations: Anclote 230 kV Seven Springs 230 kV and 115 kV Largo 230 kV Lake Tarpon 500 kV and 230 kV TECO’s Sheldon 230 kV (Third Party Impact)

Table 5.1.1 Categories B, C and D Results

CTGCY5 LL-1 LL-2 PK-1

NFLT D D D

ALDM309 D D D

ANCL300 D, 1.5LS D, 1.9LS D, 1.5LS

ANCL301 D,1.3LS,0.5GT D, 1.4LS,0.5GT D, 0.5GT

ANCL301L D,6.6LS,3.4GT,FS1 D,6.7LS,3.6GT,FS1 D,6.7LS,7.2GT,FS1,OL,UV

ANCL302 D,6.4LS,3.4GT,FS1 D,10.0LS,4.9GT,FS1,OV D,2.7LS

ANCL303 D D D

ANCL309 D,6.7LS,3.4LS,FS1 D,7.6LS,3.6LS,FS1,OV D,3.6LS,7.2GT,FS2,OL,UV

ANCL310 D, 1.8GT,UV D, 1.8GT,UV D,1.8GT

ANCL311 D,1.8GT,UV D,1.8GT,UV D,1.8GT

ANCL101 D D D

ANCL102 D D D

ANCL103 D D D

ANCL200 D D D

ANCL209 D,1.5LS,1.8GT,FS2 D,1.5LS,1.8GT LD,0.1LS,1.8GT

BKR1303R D D D

BKR2301R D D D

BKRG301T D D D

BKV1303R D D D

5 Sequence impedances are provided in Appendix III-2 for the SLG and BF faults with IPT capability.



BKVW301R D D D

CFL2301TR D D D

CFLA301T D D D

CIT2301 NA NA NA

CRP5302A D D D,0.7GT

CRPL301 D,0.7GT D,0.7GT D,0.7GT

CRPL310 D,1.8GT,UV D,2.3GT,FS2,OL,UV D,6.2LS,3.4GT,FS1

CURL309 D D D

ECL1309 D,6.5LS,4.2GT,FS1,OL,UV D,7.5LS,4.9GT,FS1,OL,UV D,3.0LS,OL,UV

ECL1209 D D D

ECLW300 D,1.5LS,OV D,1.9LS,OV D,1.5LS

ECLW301 D,1.0LS D,1.2LS,OV D

ECLW302 D,1.5LS D,1.6LS,OV D,1.5LS

ECLW303 D,1.2LS D,1.4LS,OV D,1.6LS

ECLW309 D,9.1LS,4.2GT,FS1,OV D,10.2LS,4.9GT,FS1,OV D,3.7LS,7.2GT,FS2,OL,UV

ECLW200 D D D

ECLW209 D D D

ELFR309 D D D

FLMR303 D D D

GULF300 D,1.3LS D,1.5LS,OV D


GULF301L D,6.4LS,3.4GT,FS1 D,8.1LS,3.6GT,FS1,OV D,6.2LS,7.2GT,FS1,OL,UV


GULF303 D,6.4LS,3.4GT,FS1 D,7.9LS,3.6GT,FS1,OV D,7.0LS,7.2GT,FS1,OL,UV

GULF304 D D D

GULF309 D,7.9LS,4.2GT,FS1 D,10.5LS,4.9LS,FS1,OV D,3.9LS,7.2GT,FS2,OL,UV

GULF101 D D D

GULF102 D D D

GULF103 D D D

GULF201 D D D

GULF209 D,OL D,OL D

HOLD303 D D D

HUD1300 D D D

HUD1301 D D D

HUD1302 D D D

HUD1309 D,5.1LS,1.6GT,FS1,OV D,5.6LS,1.6GT,FS1,OV D,1.7LS,0.5GT

HUD1209 D,0.5GT D,0.5GT D,0.5GT

HUDS300 D,0.5GT D,0.5GT D,0.5GT

HUDS301 D,0.8LS,0.5GT D,1.1LS,0.5GT D

HUDS302 D,1.3LS,0.5GT D,1.5LS,0.5GT D

HUDS303 D,0.5GT D,0.5GT D,0.5GT

HUDS304 D D D

HUDS309 D,6.4LS,3.4GT,FS1 D,6.7LS,3.7GT,FS1,OV D,1.6LS,0.5GT



HUDS101 D D D

HUDS201 D D D

HUDS209 D D D,0.5GT

LRGO300 D,1.2LS D,1.5LS,OV D,1.8LS

LRGO301 D,1.2LS D,1.4LS,OV D,1.5LS

LRGO303 D,1.9LS,OV D,1.9LS,OV D,2.6LS,0.5GT

LRGO309 D,9.1LS,4.2GT,FS1,OV D,10.2LS,4.9GT,FS1,OV D,6.5LS,7.2GT,FS1,OL,UV

LRGO101 D D D

LRGO200 D D D

LRGO209 D D D,OL

LROW301 D, 0.5GT D, 0.5GT D, 0.5GT

LROW302 D D D

LROW303 D D,OL D,OL

LROW304 D,OL D,OL D

LTP2300 D,1.2LS D,1.5LS,OV D,1.4LS

LTP2301 D,1.5LS D,1.7LS,OV D,1.5LS

LTP2302 D,1.9LS,OV D,1.9LS,OV D,1.6LS

LTP2304 D,7.8LS,4.2GT,FS1 D,9,4LS,4.9GT,FS1,OV D,3.0LS

LTP2305 D D D

LTP2309 D,7.4LS,4.2GT,FS1 D,9.1LS,4.9GT,FS1,OV NC

LTP2101 D D D

LTP2102 D D D

LTP2200 D D D

LTP2209 D,7.6LS,4.2GT,FS1,OV D,9.9LS,5.5GT,FS1,OV D,0.5LS,OL

LTPN301 D D D

LTPN309 D,1.9LS,4.3GT,FS2,OL,UV D,5.6LS,4.9GT,FS1,OL,UV D,3.8LS,7.2GT,FS2,OL,UV

LTPN101 D D D

LTPN209 D, OL D, OL D,OL

NWPR309 D D D

PMHR309 D,9.3LS,4.8GT,FS1,OV D,10.1LS,5.5GT,FS1,OV D,6.0LS,7.2GT,FS1,UL,UV

PMHR209 D D D

SEV1300 D D D

SEV1301 D D D

SEV1301L D D D

SEV1302 D D D

SEV1303 D D D

SEV1309 D,7.6LS,4.2GT,FS1 D,10.1LS,5.6GT,FS1,OV D,5.9LS,7.2GT,FS1,OL,UV

SEV1101 D D D

SEV1102 D D D

SEV1209 D D D,OL

SEVS300 D,1,9LS,OV D,1.9LS,OV D,1.0LS

SEVS301 D,1.9LS,OV D,1,9LS,OV D,1.5LS

SEVS301L D,6.7LS,3.4GT,FS1 D,9.0LS,5.6GT,FS1,OV D,7.1LS,7.2GT,FS1,OL,UV



SEVS302 D,6.7LS,3.4GT,FS1 D,9.0LS,5.6GT,FS1,OV D,6.9LS,7.2GT,FS1,OL,UV

SEVS303 D,6.7LS,3.4GT,FS1 D,6.7LS,3.6GT,FS1,OV D,3.5LS,1.8GT

SEVS309 D,8.9LS,4.8GT,FS1,OV D,10.4LS,5.6GT,FS1,OV D,3.2LS,7.1GT,FS2,OL,UV

SEVS101 D D D

SEVS201 D D D

SEVS209 D D D,OL

SHEL301 D,9.1LS,4.8GT,FS1,OV D,11.8LS,7.4GT,FS1,OV D,6.1LS,7.2GT,FS1,OL,UV

BASE D,5.5LS,2.8GT,FS1,OV D,5.4LS,6.6GT,FS2,OL,UV

SHEL304 D,6.9LS,4.2GT,FS1 D,11.8LS,7.5GT,FS1,OV D,6.6LS,7.2GT,FS1,OL,UV

BASE D,6.1LS,2.8GT,FS1 D,6.6LS,3.4GT,FS1

SHEL309 D,9.0LS,6.7GT,FS1,OL,UV D,11.6LS,7.3GT,FS1,OV NC

BASE D,9.9LS,6.6GT,FS1,OL,UV NC

SHEL101 D D D

SHEL201 D D D

SHEL204 D D D

SHEL209 D,1.0LS,OL,OV D,1.0LS,OL,OV D,OL

BASE D,1.0LS, OL D,OL

TPNS309 D,1.5LS D,.15LS,OV D

TPNS209 D D D

ULMR303 D,1.2LS D,1.3LS,OV D

ULMR304 D,1.5LS D,1.5LS,OV D,1.5LS

ULMR204 D D D

D=Damped, LD=Lightly Damped–but meets criteria, UNS=Transiently unstable response resulting in wide spread system collapse or Transiently stable response with undamped power system oscillations, FS1=Florida separates from Eastern Interconnection, FS2=Florida separates at Fort White, x.xLS=GW Load Shedding initiated by automatic UFLS, x.xGT=GW Generation tripped either as part of the fault or on overspeed/OOS protection, OV=Overvoltages above 1.8pu, UV=Undervoltages below 0.9pu, OL=Overloads above 110% of Emergency Rating (B).

5.2 Assessment of NERC Category D Contingencies

Table 5.1.1 summarizes the contingency results for NERC categories D2, D7, D8 and D10 contingencies with the Project interconnecting to the system at the Anclote 230 kV substation. For the category D2 contingencies, three phase faults accompanied by either circuit breaker or relay failure were simulated at the Anclote substation and other area substations as listed in Section 4. Transient stability output plots are provided in Appendix IV and contingency switching details in Appendix III-1. The following protection systems upgrades will focus on the contingencies at the 500 kV, 230 kV and 115 kV voltage levels that exhibited unacceptable system response: Anclote Substation: For a 230 kV breaker failure contingency, the BFBU time should be 9.9 cycles and the DTT to the adjacent facility 1.0 cycle. There should be two independent HSPP groups. The 230 kV bus should have independent redundant high speed protection systems.


Seven Springs Substation: For a 230 kV breaker failure contingency, the BFBU time should be 11.0 cycles and the DTT to the adjacent facility 1.0 cycle. There should be two independent HSPP groups. The 230 kV bus should have independent redundant high speed protection systems. For a 115 kV breaker failure contingency, the BFBU time should be 15.0 cycles. There should be two independent protection groups one being HSPP. The Z2 clearing for the step distance group should be 30 cycles. The 115 kV bus should have independent redundant high speed protection systems. Hudson Substation: For a 230 kV breaker failure contingency, the BFBU time should be 12.0 cycles. There should be two independent protection groups one being HSPP. The Z2 clearing for the step distance group should be 30 cycles. The 230 kV bus should have independent redundant high speed protection systems. For a 115 kV breaker failure contingency, the BFBU time should be 17.0 cycles. There should be two independent protection groups one being HSPP. The Z2 clearing for the step distance group should be 35 cycles and the 115 kV bus should have independent redundant high speed protection system. East Clearwater Substation: For a 230 kV breaker failure contingency, the BFBU time should be 14.0 cycles and the DTT to the adjacent facility 1.0 cycle. There should be two independent protection groups one being HSPP. The Z2 clearing for the step distance group should be 30 cycles. The 230 kV and 115 kV busses should have independent redundant high speed protection systems. Largo Substation: For a 230 kV breaker failure contingency, the BFBU time should be 15.0 cycles and the DTT to the adjacent facility 1.0 cycle. There should be two independent protection groups one being HSPP. The Z2 clearing for the step distance group should be 35 cycles. The 230 kV bus should have independent redundant high speed protection systems. Lake Tarpon Substation: For a 500 kV breaker failure contingency, the BFBU time should be 10.2 cycles and the DTT to the adjacent facility 1.0 cycle. There should be two independent HSPP groups. For a 230 kV breaker failure contingency, the BFBU time should be 10.0 cycles and the DTT to the adjacent facility 1.0 cycle. The 500 kV and 230 kV busses should have independent redundant high speed protection systems. Other Local Substations: Category D contingency at other local substations were damped and no overloads or over/under voltages were observed. Third Party Impact: For the light and peak load base cases, category D contingencies at the Sheldon Rd 230 kV substation caused a large activation of automatic UFLS, generation trip on overspeed protection and Florida separation from the EI. The following are the proposed clearing times for the new facilities: Gulf Pine Substation: For a 230 kV breaker failure contingency, the BFBU time should be 9.0 cycles and the DTT to the adjacent facility 1.0 cycle. There should be two independent


HSPP groups. The 230 kV bus should have independent redundant high speed protection systems. The category D10 contingency tested showed a damped response. The Category D8 contingencies tested showed a damped response and some undervoltage condition at the Fort White area for the contingencies where no separation from the Eastern Interconnection occurred. The loss of all generating units at Crystal River caused the separation of Florida from the Eastern Interconnection. The Category D7 contingencies tested showed a damped response, however a slight overload condition at the Weeki Wachee area for the loss of right-of-way south of Brookridge and overload conditions at the Tarpon Springs and E.Clearwater areas for the loss of right-of-way north of Lake Tarpon were observed.

6.0 Conclusions and Recommendations The result of the transient stability study indicates that the addition of the Project, its associated reinforcements and required transmission system upgrades will have no significant impact on the transient stability response of the bulk transmission system. The proposed Project will interconnect to the Progress Energy transmission system at the existing Anclote 230 kV substation in Pasco County and it will include new transmission facilities and the upgrade of several existing transmission facilities as discussed in Sections 2 and 3. The following protection systems upgrades and/or improvements will be implemented at the following substations as part of the Anclote Phase I project previous to its interconnection to the Progress Energy Florida transmission system: Gulf Pine 230 kV Anclote 230 kV Seven Springs 230 kV and 115 kV Hudson 230 kV and 115 kV East Clearwater 230 kV Installation of Out of Step Protection relays (OOS) on each Anclote generating unit. Installation of Power System Stabilizers (PSS) on each CT generating unit.

The gross cost estimate for the above upgrades is $9 Million. All relevant plants and firm transactions ahead of the Project in the FRCC combined Long-Term Firm Transmission and Generation Interconnection Service Requests Queue were modeled in this study. In addition, this study includes analysis for the retirement of the Crystal River units 1 and 2 and its proposed upgrades. Upgrades and/or improvements of protection systems and associated clearing times should be implemented at the Lake Tarpon 500 kV and 230 kV, Largo 230 kV, and Palm Harbor 230 kV for which the Project is not responsible. These upgrades should be done as part of Progress Energy regular transmission planning process. In addition, study results for the base cases showed system


response issues at the Sheldon Rd 230 kV substation that should be address with TECO as a third party impacted utility. The thermal and voltage analyses are provided in a separate report. Any changes or modifications to the present proposal for the Project will require additional study work to identify new impacts to the transmission system.

OCTOBER 2012. SIS ANCLOTE PHASE I PROJECT TRANSIENT STABILITY REPORT I-1

APPENDIX I Loadflow Summaries

********************************************************************** CASE :2015 SUMMER PEAK LOAD, SOU-FLA = 3700 MW FRCC LFDB (8/24/09), MODIFIED FOR DYNAMICS ********************************************************************** STATION VOLTAGES CRYSTAL RVR = 525.7 CENTRAL FLA = 512.9 BROOKRIDGE = 528.0 LK TARPON = 531.9 KATHLEEN = 517.1 DUVAL = 518.7 POINSETT = 523.5 MARTIN = 520.0 8THALMANN = 514.2 8N TIFTON = 513.5 8HATCH = 517.1 CRYST RVR PL = 239.8 CENTRAL FLA = 226.6 DEBARY = 235.3 N LONGWOOD = 232.9 WOODSMERE = 225.5 ANCLOTE = 239.9 BARTOW = 240.1 40 STREET = 237.2 NORTHEAST = 239.8 LARGO = 237.1 ULMERTON = 238.6 SEMINOLE = 235.9 PASADENA = 236.1 LK TARPON-A = 234.4 LK TARPON-B = 234.5 3CATOMATP = 116.0* PERRY = 226.2 SUWANNEE RV = 226.1 FT WHITE N = 228.9 FT WHITE S = 229.0 NEWBERRY = 230.4 GINNIE = 228.0 AVON PARK = 236.4 FT MEADE = 237.8 INTERCSN CTY = 226.4 VANDOLAH = 235.4 W LAKE WALES = 232.4 HINES ENERGY = 238.8 HIGGINS = 232.9 PORT ST JOE = 226.3 MIDWAY = 238.9 RANCH = 235.6 ST LUCIE = 239.5 MANATEE = 239.6 POINSETT = 235.9 PUTNAM = 233.4 WEST = 234.5 METRO W = 223.5* SHELDON ROAD = 233.8 6PINEGRVE = 227.2 8FARLEY 8 = 520.0* PERRY = 138.8* TURNER PLANT = 116.3 HIGGINS = 118.3 BARTOW = 118.3 40 STREET = 118.2 NORTHEAST = 118.2 ULMERTON = 118.2 PASADENA = 118.5 INGLIS = 116.8 BROOKRIDGE = 118.5 BROOKSVL W = 118.3 JASPER = 114.8 7 SPRINGS A = 118.6 FT WHITE = 118.3 GRIFFIN = 117.6 OCCIDENT2 TP = 112.8 GENERATOR/SVC QUANTITIES GENERATOR MW PMAX PMIN MVAR QMAX QMIN VSCHED VTBUS CRYST RVR G3 1080.0*1020.0 203.0 191.6 393.0 50.0 1.0150 1.0150 CRYST RVR G5 720.0* 720.0 177.5 158.3 310.0 -40.0 1.0191 1.0191 CRYST RVR G1 386.0* 386.0 94.8 170.8 190.0 -10.0 1.0831 1.0831 CRYST RVR G2 482.3 494.0 124.5 172.1 257.0 -33.0 1.0147 1.0147 CRYST RVR G4 722.0* 722.0 182.2 172.0 310.0 -40.0 1.0886 1.0886 PASCO RR 23.0* 23.0 5.8 10.3 19.0 -12.0 1.0400 1.0400 FCS CP&L 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9788 FCS CP&L 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9788 ANCLOTE STMA 438.0* 438.0 126.0 118.1 216.0 -27.7 1.0430 1.0193 ANCLOTE G2 510.0* 510.0 125.8 118.1 257.0 -33.0 1.0430 1.0185 SHADY HLS P1 162.0* 162.0 50.0 22.2 45.0 -45.0 1.0300 1.0300 SHADY HLS P2 162.0* 162.0 50.0 22.2 45.0 -45.0 1.0300 1.0300 SHADY HLS P3 162.0* 162.0 50.0 22.2 45.0 -45.0 1.0300 1.0300 HIGGINS P1&2 50.0* 50.0 14.4 0.4 40.0 -6.0 0.9791 0.9791 HIGGINS P3&4 60.0* 60.0 17.5 1.1 48.0 -6.0 0.9787 0.9787 BARTOW P1&2 86.0* 86.0 23.0 -0.5 44.0 -10.0 1.0180 1.0180 BARTOW P3&4 47.0 94.0 24.4 -1.8 44.0 -10.0 1.0124 1.0124 BARTOW CT4A 178.8 179.0 28.2 68.1 70.0 -40.0 1.0991 1.0991 BARTOW CT4B 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0650 BARTOW CT4C 178.8 179.0 28.2 68.1 70.0 -40.0 1.0991 1.0991 BARTOW CT4D 178.8 179.0 28.2 68.1 70.0 -40.0 1.0991 1.0991 BARTOW ST4 462.5 463.0 90.2 68.9 272.0 -40.0 1.0771 1.0771 PINELLAS RR1 40.0* 40.0 10.0 6.2 23.0 -18.0 1.0430 1.0430 PINELLAS RR2 14.8* 14.8 3.7 7.3 23.0 -18.0 1.0430 1.0430 BAYORO P1&3 86.0 90.0 23.5 -1.0 44.0 -10.0 0.9902 0.9902 BAYORO P2&4 86.0 87.0 23.5 -1.0 44.0 -10.0 0.9902 0.9902 HINES CT1A 157.2* 157.2 41.0 46.8 100.0 -50.0 1.0398 1.0398 HINES CT1B 157.2* 157.2 41.0 46.8 100.0 -50.0 1.0398 1.0398 HINES CT2A 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0131 HINES CT2B 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0131 HINES CT3A 166.3* 166.3 41.0 46.5 92.0 -45.0 1.0401 1.0401 HINES CT3B 166.3* 166.3 41.0 46.5 92.0 -45.0 1.0400 1.0400 HINES CT4A 160.8* 160.8 41.0 47.9 92.0 -45.0 1.0409 1.0409 HINES CT4B 160.8* 160.8 41.0 47.9 92.0 -45.0 1.0409 1.0409 HINES ST1 147.6* 147.6 38.5 46.9 95.0 -40.0 1.0398 1.0398 HINES ST2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0131 HINES ST3 155.4* 155.4 40.0 86.0* 86.0 -43.0 0.9810 0.9771 HINES ST4 88.0 150.3 40.0 46.3 86.0 -43.0 1.0388 1.0388 INTERCSN P7 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9656 INTERCSN P8 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9656 INTERCSN P9 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9656 INTERCSN P10 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9656


INTERCSN P11 143.0* 143.0 35.8 20.4 70.0 -40.0 0.9951 0.9951 INTERCSN P12 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9603 INTERCSN P13 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9603 INTERCSN P14 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9603 INTERCSN 1&2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9995 INTERCSN 3&4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9995 INTERCSN 5&6 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9995 TIGERBAY CG1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0105 TIGERBAY CG2 10.0* 42.0 10.5 21.8 45.0 -30.0 1.0430 1.0430 TURNER P1&2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9991 TURNER P3&4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9580 ORLANDO CG 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9677 ORANGE CG1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0253 ORANGE CG2 41.7* 41.7 10.4 7.8 25.0 -20.0 1.0400 1.0400 DEBARY P1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9319 DEBARY P2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9319 DEBARY P3 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9319 DEBARY P4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9319 DEBARY P5 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9319 DEBARY P6 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9319 DEBARY P7 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0492 DEBARY P8 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0492 DEBARY P9 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0492 DEBARY P10 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0492 UNIVERSTY FL 35.0* 35.0 9.0 8.8 20.0 -20.0 1.0291 1.0291 SUWANNE P1&2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.8955 SUWANNEE P3 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9171 SUWANNEE G1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9769 SUWANNEE G2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9766 SUWANNEE G3 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9811 ANCLOTE CTA1 297.0* 297.0 165.0 118.1 170.0 -72.5 1.0430 1.0336 ANCLOTE CTA2 297.0* 297.0 165.0 118.1 170.0 -72.5 1.0430 1.0336 ANCLOTE CTA3 297.0* 297.0 165.0 118.1 170.0 -72.5 1.0430 1.0336 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.0000 GENERATOR COMPLEX REPORT GEN COMPLEX ON OFF MW SPRES PMAX PMIN MVAR REMVAR QMAX QMIN AR-2-PEF 51 56 8963. 52. 12564. 3371. 2395. 2051. 6572. -2286. CRYS-RIV-GEN500 2 0 1800. -60. 1740. 380. 350. 353. 703. 10. CRYS-RIV-GEN230 3 0 1590. 12. 1602. 402. 515. 242. 757. -83. PASCO+FCS 1 2 23. 0. 148. 37. 10. 9. 80. -20. ANCLOTE 5 0 1839. 0. 1839. 747. 591. 392. 983. -278. SHADY 3 0 486. 0. 486. 150. 67. 68. 135. -135. BARTOW 7 2 1132. 1. 1359. 250. 271. 277. 640. -220. BAYBORO+COVE 6 0 227. 5. 232. 61. 12. 122. 134. -56. HIGGING 4 0 110. 0. 110. 32. 2. 86. 88. -12. HINES 9 3 1360. 62. 1912. 494. 462. 373. 1155. -564. INTERSECCION-CI 1 13 143. 0. 988. 249. 20. 50. 637. -286. AR-1-FPL 108 45 21102. 181. 27042. 11805. 5186. 8707. 16931. -9755. AR-6-JEA 8 9 2510. 353. 3834. 1403. 928. 542. 1800. -780. AR-11-FMPP 19 19 3194. 48. 3887. 1560. 1282. 449. 2006. -828. AR-12-SEC 10 0 2072. -4. 2068. 920. 82. 1127. 1209. -631. AR-15-TAL 4 4 341. 181. 714. 285. 202. 141. 448. 0. AR-16-TECO 33 6 4431. 394. 4971. 1832. 1545. 1493. 3185. -1030. AR-21-TCEC 2 0 344. 0. 344. 100. 231.* 0. 231. -60. AR-4-GVL 5 7 401. 135. 712. 352. 97. 155. 337. 0. INTERFACE FLOW REPORT DESCRIPTION MW MVAR DESCRIPTION MW MVAR SOCO-FPL-a 2562.5 -366.2 SOCO-PEF-a 896.2 -186.7 SOCO-TAL-a 241.4 -62.3 SOCO-FLORIDA-a 3700.1 -615.2 CR-SOUTH 932.8 25.5 CR-SOUTH+115 996.9 36.0 BK-SOUTH 453.9 11.6 BK-SOUTH+115 515.2 10.9 SHUNT REPORT SHNTNAME SHACT SHTOT SHNTNAME SHACT SHTOT SHNTNAME SHACT SHTOT (-ind,+cap) (-ind,+cap) (-ind,+cap) LKTARPN-TER1 0. -50. LKTARPN-TER2 0. -78. BRKRDG1-TER 0. -50. CFLA-TER2 0. -25. CFLA-TER5 0. -25. KATHLEEN-TER 0. -75. ULMERTON 160. 149. 40 STREET 0. 75. LARGO A 80. 76. SEMINOLE 0. 25. WALSINGHAM 0. 32. PIEDMONT 147. 149. WINDERMERE 82. 78. SUWANNEE RV 72. 75. FT WHITE S 74. 74. ATWATER 40. 40. HAVANA 0. 27. TRANSFORMER FLOW REPORT TRANSFORMER CNTL MW MVAR PF TAP TAP RANGE


FT WHITE N 230. -FT WHITE 1 94.6 35.9 0.9348* 0.9891 1.0983/0.8943 FT WHITE 115. -FT WHITE 1 -31.6 -35.6 -0.6642* 0.9876 1.0953/0.8961 GINNIE 230. -GINNIE 1 56.2 -10.3 0.9836 1.0303 1.0684/0.8741 TRANSMISSION LINE FLOW REPORT LINE RATEA RATEB RATEC MVA MW ------ MVAR ----------- FROM TO NET CHG CRYSTAL RVR 500. -BROOKRIDGE2598. 2598. 3637. 528. 518. -103. 56. -47. 0. BROOKRIDGE 500. -LK TARPON 1732. 1732. 2425. 331. 305. -129. 67. -62. 0. CRYSTAL RVR 500. -CENTRAL FL2598. 2598. 3637. 1243. 1226. 202. -99. 103. 0. CENTRAL FLA 500. -KATHLEEN 750. 750. 1050. 144. 51. -134. 54. -80. 0. CRYST RVR PL230. -LECANTO 677. 813. 948. 198. 185. 70. -68. 2. 0. CRYST RVR PL230. -HOLDER 677. 745. 948. 429. 417. 103. -68. 35. 0. HOLDER 230. -CENTRAL FL 656. 797. 918. 277. 273. 45. -18. 27. 0. HOLDER 230. -ROSS PRAIR 677. 745. 948. 438. 431. 79. -52. 26. 0. ANDERSEN 230. -ROSS PRAIR 637. 637. 892. 240. -239. -15. 21. 6. 0. FT WHITE N 230. -SUWANNEE R 492. 604. 689. 112. -107. 34. -37. -3. 0. FT WHITE S 230. -FT WHITE N1195. 1195. 1673. 71. -12. 70. -70. 0. 0. GINNIE 230. -FT WHITE S 454. 542. 636. 160. -160. 2. -1. 1. 0. NEWBERRY 230. -FT WHITE S 492. 604. 689. 149. 149. -3. 4. 1. 0. CRYST RVR PL230. -KING ROAD 492. 604. 604. 323. 321. 37. -23. 14. 0. SLV_SP_N 230. -MARTIN WES 385. 385. 385. 135. 135. 11. -11. 0. 0. CENTRAL FLA 230. -DALLAS 677. 813. 948. 241. 240. 26. -19. 6. 0. ULMERTON 230. -LK TARPON- 637. 637. 892. 87. 50. 71. -75. -4. 0. ULMERTON 230. -NORTHEAST 677. 813. 948. 224. -214. -64. 65. 1. 0. ULMERTON 230. -NORTHEAST 677. 813. 948. 224. -214. -64. 65. 1. 0. BARTOW 230. -NORTHEAST 425. 460. 595. 266. 266. 10. -47. -37. 0. BARTOW 230. -NORTHEAST 425. 460. 595. 266. 266. 10. -47. -37. 0. BARTOW 230. -NORTHEAST 584. 785. 818. 195. 191. 39. -68. -29. 0. BARTOW 230. -NORTHEAST 584. 785. 818. 209. 205. 42. -71. -29. 0. BARTOW 230. -NORTHEAST 584. 785. 818. 206. 202. 41. -71. -30. 0. BARTOW 115. -40 STREET 64. 82. 90. 38. 34. -18. -1. -18. 0. BARTOW 115. -40 STREET 64. 82. 90. 38. 34. -18. -1. -18. 0. BARTOW 115. -NORTHEAST 82. 103. 115. 38. -34. 18. -25. -7. 0. BARTOW 115. -NORTHEAST 82. 103. 115. 38. -34. 18. -25. -7. 0. LBMP AREA REPORT N AREA NAME LOAD MW MVAR PF LOAD+LOSSES MW PLNT MW MVAR LOSS MW MVAR GEN MW MVAR INT MW MVAR 1 FPL 23648. 7394. 0.9544 24171. 0. 0. 522. 7576. 21102. 5186. -3069. 896. 2 PEF 12123. 3161. 0.9676 12404. 0. 0. 281. 3740. 8963. 2395. -3452. -972. 3 FTP 112. 26. 0.9750 113. 0. 0. 1. 5. 8963. 2395. -113. -10. 4 GVL 467. 103. 0.9766 471. 0. 0. 4. 40. 401. 97. -69. 42. 5 HST 101. 25. 0.9699 101. 0. 0. 0. 2. 33. 0. -68. -22. 6 JEA 3058. 1077. 0.9432 3102. 0. 0. 44. 691. 2510. 928. -592. -161. 7 KEY 140. 28. 0.9801 143. 0. 0. 4. 27. 32. 38. -111. 30. 9 LWU 90. 23. 0.9700 91. 0. 0. 0. 10. 30. 14. -61. -18. 10 NSB 97. 24. 0.9700 98. 0. 0. 1. 8. 58. 58. -39. 29. 11 FMPP 2423. 475. 0.9813 2467. 0. 0. 44. 782. 3194. 1282. 727. 347. 12 SEC 312. 83. 0.9667 367. 0. 0. 55. 559. 2072. 82. 1705. -412. 15 TAL 546. 161. 0.9591 553. 0. 0. 7. 59. 341. 202. -212. 122. 16 TECO 4292. 1321. 0.9557 4365. 0. 0. 73. 1074. 4431. 1545. 66. 281. 17 VER 176. 36. 0.9800 178. 0. 0. 2. 18. 28. 80. -151. 62. 18 NUG 176. 36. 0.9800 177. 0. 0. 1. 26. 250. 82. 249. 56. 19 RCU 201. 71. 0.9431 203. 0. 0. 2. 25. 54. 3. -149. -2. 21 TCEC 201. 71. 0.9431 202. 0. 0. 1. 58. 344. 231. 343. 173. 26 OSC 0. 0. 1.0000 0. 0. 0. 0. 0. 0. 0. 0. 1. 27 OLEANDER 0. 0. 1.0000 0. 0. 0. 0. 12. 140. 41. 139. 29. 28 CALPINE 0. 0. 1.0000 0. 0. 0. 0. 0. 150. 1. 150. 1. 31 VAN 0. 0. 1.0000 4. 0. 0. 4. 61. 650. 118. 646. 58. 33 HPS 0. 0. 1.0000 4. 0. 0. 4. 89. 365. 169. 361. 87. 36 DESOTOGN 0. 0. 1.0000 0. 0. 0. 0. 0. 0. 0. 0. 0. 38 IPP-REL 0. 0. 1.0000 0. 0. 0. 0. 0. 0. 0. 0. 0. AREA TOTAL 48165. 14115. 0.9596 49214. 0. 0. 1049. 14861. 54110. 14947. -3700. 615. LBMP ZONE REPORT LBMP ZONE NAME NUM LOAD MW MVAR PF LOSS MW MVAR ST. PETE 51 666.8 162.5 0.9716 1.9 31.7 SVN SPRINGS 53 766.2 168.5 0.9767 5.7 42.9 INVERNESS 55 299.5 60.8 0.9800 1.6 20.2 LAKE WALES 57 450.1 115.0 0.9689 7.1 32.2 WNTR GARDEN 59 404.4 101.5 0.9699 4.4 26.9 APOPKA 61 491.4 99.8 0.9800 2.0 11.0 JAMESTOWN 63 654.5 200.8 0.9560 2.9 25.4 DELAND 65 372.0 84.8 0.9750 0.8 4.4


MONTICELLO 67 265.5 53.2 0.9805 3.8 13.1 OCALA 69 0.0 0.0 7.9 51.4 MONTICEL 71 0.0 0.0 0.0 0.4 PEF GENS 90 87.7 58.9 0.8302 11.8 754.5 COGENS 92 21.1 12.1 0.8666 0.7 19.7 NOLOAD 100 32.0 6.1 0.9824 196.2 2446.8 BUSHNELL 281 6.1 1.4 0.9746 0.0 0.0 LEESBURG 282 122.5 25.9 0.9783 0.8 11.1 OCALA 283 321.8 61.9 0.9820 1.4 24.0 NW 301 553.0 133.2 0.9722 14.4 67.2 NORTHEST 302 418.1 148.7 0.9422 6.9 21.5 CENTRAL 303 1118.4 149.2 0.9912 18.6 131.5 KAMO 304 133.7 101.3 0.7972 9.5 33.6 SUMTER 305 838.7 169.2 0.9803 4.0 8.5 SHO-ME 306 1039.4 260.9 0.9699 18.1 107.0 M&A 307 670.8 213.6 0.9529 12.8 61.5 TRI-CNTY 308 72.8 20.7 0.9618 0.1 0.3 WTHLCHEE 309 1102.3 359.1 0.9508 1.6 6.5 GORDONSV 363 826.1 244.2 0.9590 11.7 147.3 VALLEY 364 991.5 381.1 0.9334 9.8 184.0 436 15.0 1.3 0.9963 0.0 0.0 ZONE-TOTAL LOAD & LOSS MW AND PF 12741.6 356.6 0.9663 ********************************************************************** CASE :2015 SUMMER 50% LOAD LEVEL, SOU-FLA=3700 MW FRCC LFDB REV1 (8/19/10) MODIFIED FOR DYNAMICS ********************************************************************** STATION VOLTAGES CRYSTAL RVR = 531.6 CENTRAL FLA = 529.6 BROOKRIDGE = 534.0 LK TARPON = 536.7 KATHLEEN = 531.8 DUVAL = 518.5 POINSETT = 525.4 MARTIN = 525.3 8THALMANN = 518.0 8N TIFTON = 516.6 8HATCH = 517.5 CRYST RVR PL = 239.2 CENTRAL FLA = 235.5 DEBARY = 235.9 N LONGWOOD = 235.5 WOODSMERE = 233.9 ANCLOTE = 239.9 BARTOW = 237.5 40 STREET = 235.9 NORTHEAST = 237.4 LARGO = 236.2 ULMERTON = 236.8 SEMINOLE = 235.7 PASADENA = 235.8 LK TARPON-A = 236.1 LK TARPON-B = 236.1 3CATOMATP = 116.9* PERRY = 230.0 SUWANNEE RV = 234.1 FT WHITE N = 236.0 FT WHITE S = 236.1 NEWBERRY = 238.2 GINNIE = 235.6 AVON PARK = 235.7 FT MEADE = 236.9 INTERCSN CTY = 232.8 VANDOLAH = 239.2 W LAKE WALES = 235.8 HINES ENERGY = 237.1 HIGGINS = 235.4 PORT ST JOE = 223.9* MIDWAY = 240.7 RANCH = 236.9 ST LUCIE = 240.3 MANATEE = 239.0 POINSETT = 238.3 PUTNAM = 233.3 WEST = 236.2 METRO W = 232.7 SHELDON ROAD = 236.0 6PINEGRVE = 233.5 8FARLEY 8 = 517.9* PERRY = 139.5* TURNER PLANT = 117.5 HIGGINS = 118.2 BARTOW = 117.9 40 STREET = 118.2 NORTHEAST = 117.7 ULMERTON = 117.7 PASADENA = 117.9 INGLIS = 117.6 BROOKRIDGE = 118.2 BROOKSVL W = 118.1 JASPER = 118.2 7 SPRINGS A = 118.1 FT WHITE = 121.1* GRIFFIN = 117.8 OCCIDENT2 TP = 116.8 GENERATOR/SVC QUANTITIES GENERATOR MW PMAX PMIN MVAR QMAX QMIN VSCHED VTBUS CRYST RVR G3 1080.0*1020.0 203.0 63.8 393.0 50.0 1.0095 1.0095 CRYST RVR G5 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0126 CRYST RVR G1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0401 CRYST RVR G2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9928 CRYST RVR G4 722.0* 722.0 182.2 138.4 310.0 -40.0 1.0819 1.0819 PASCO RR 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0014 FCS CP&L 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9761 FCS CP&L 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9761 ANCLOTE STMA 438.0* 438.0 126.0 88.7 216.0 -27.7 1.0430 1.0123 ANCLOTE G2 510.0* 510.0 125.8 88.7 257.0 -33.0 1.0430 1.0113 SHADY HLS P1 162.0* 162.0 50.0 -18.8 45.0 -45.0 0.9969 0.9969 SHADY HLS P2 162.0* 162.0 50.0 -18.8 45.0 -45.0 0.9969 0.9969 SHADY HLS P3 162.0* 162.0 50.0 -18.8 45.0 -45.0 0.9969 0.9969 HIGGINS P1&2 50.0* 50.0 14.4 1.3 40.0 -6.0 0.9801 0.9801 HIGGINS P3&4 60.0* 60.0 17.5 2.0 48.0 -6.0 0.9797 0.9797 BARTOW P1&2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0078 BARTOW P3&4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0022 BARTOW CT4A 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0532 BARTOW CT4B 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0532 BARTOW CT4C 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0532 BARTOW CT4D 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0532 BARTOW ST4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0532


PINELLAS RR1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0175 PINELLAS RR2 5.0 14.8 3.7 1.4 23.0 -18.0 1.0014 1.0014 BAYORO P1&3 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9934 BAYORO P2&4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9934 HINES CT1A 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0056 HINES CT1B 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0056 HINES CT2A 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0056 HINES CT2B 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0056 HINES CT3A 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0056 HINES CT3B 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0056 HINES CT4A 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0105 HINES CT4B 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0105 HINES ST1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0056 HINES ST2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0056 HINES ST3 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9218 HINES ST4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0105 INTERCSN P7 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9930 INTERCSN P8 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9930 INTERCSN P9 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9930 INTERCSN P10 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9930 INTERCSN P11 143.0* 143.0 35.8 2.0 70.0 -40.0 1.0119 1.0119 INTERCSN P12 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9875 INTERCSN P13 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9875 INTERCSN P14 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9875 INTERCSN 1&2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0043 INTERCSN 3&4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0043 INTERCSN 5&6 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0043 TIGERBAY CG1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0052 TIGERBAY CG2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0052 TURNER P1&2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0041 TURNER P3&4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9679 ORLANDO CG 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9848 ORANGE CG1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0274 ORANGE CG2 41.7* 41.7 10.4 6.6 25.0 -20.0 1.0400 1.0400 DEBARY P1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9342 DEBARY P2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9342 DEBARY P3 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9342 DEBARY P4 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9342 DEBARY P5 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9342 DEBARY P6 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9342 DEBARY P7 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0518 DEBARY P8 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0518 DEBARY P9 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0518 DEBARY P10 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0518 UNIVERSTY FL 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 1.0248 SUWANNE P1&2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9272 SUWANNEE P3 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9495 SUWANNEE G1 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9772 SUWANNEE G2 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9769 SUWANNEE G3 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.9813 ANCLOTE CTA1 297.0* 297.0 165.0 88.7 170.0 -72.5 1.0430 1.0221 ANCLOTE CTA2 297.0* 297.0 165.0 88.7 170.0 -72.5 1.0430 1.0221 ANCLOTE CTA3 297.0* 297.0 165.0 88.7 170.0 -72.5 1.0430 1.0221 0.0* 0.0 0.0 0.0* 0.0 0.0 0.0000 0.0000 GENERATOR COMPLEX REPORT GEN COMPLEX ON OFF MW SPRES PMAX PMIN MVAR REMVAR QMAX QMIN AR-2-PEF 20 87 4546. -50. 12564. 3371. 610. 1488. 6572. -2286. CRYS-RIV-GEN500 1 1 1080. -60. 1740. 380. 64. 329. 703. 10. CRYS-RIV-GEN230 1 2 722. 0. 1602. 402. 138. 172. 757. -83. ANCLOTE 5 0 1839. 0. 1839. 747. 444. 539. 983. -278. SHADY 3 0 486. 0. 486. 150. -56. 191. 135. -135. BAYBORO+COVE 1 5 5. 10. 232. 61. 1. 22. 134. -56. HIGGING 4 0 110. 0. 110. 32. 3. 85. 88. -12. INTERSECCION-CI 1 13 143. 0. 988. 249. 2. 68. 637. -286. AR-1-FPL 41 ** 9039. 575. 27042. 11805. 1317. 4164. 16931. -9755. AR-6-JEA 3 14 951. 261. 3834. 1403. 261. 439. 1800. -780. AR-11-FMPP 6 32 1572. 218. 3887. 1560. 445. 507. 2006. -828. AR-12-SEC 2 8 1254. 56. 2068. 920. 200. 535. 1209. -631. AR-15-TAL 1 7 63. 77. 714. 285. 48. 35. 448. 0. AR-16-TECO 14 25 2260. 316. 4971. 1832. 767. 561. 3185. -1030. AR-21-TCEC 1 1 145. 27. 344. 100. 139. 9. 231. -60. AR-4-GVL 1 11 165. 60. 712. 352. 0.* 115. 337. 0. INTERFACE FLOW REPORT DESCRIPTION MW MVAR DESCRIPTION MW MVAR SOCO-FPL-a 2607.5 -288.5 SOCO-PEF-a 911.2 -185.1 SOCO-TAL-a 180.8 -29.1 SOCO-FLORIDA-a 3699.5 -502.7 CR-SOUTH 593.4 -73.1 CR-SOUTH+115 625.0 -72.2


BK-SOUTH 350.7 14.2 BK-SOUTH+115 384.9 12.8 SHUNT REPORT SHNTNAME SHACT SHTOT SHNTNAME SHACT SHTOT SHNTNAME SHACT SHTOT (-ind,+cap) (-ind,+cap) (-ind,+cap) LKTARPN-TER1 0. -50. LKTARPN-TER2 0. -78. BRKRDG1-TER 0. -50. CFLA-TER2 0. -25. CFLA-TER5 0. -25. KATHLEEN-TER 0. -75. ULMERTON 0. 149. 40 STREET 0. 75. LARGO A 0. 76. SEMINOLE 0. 25. WALSINGHAM 0. 32. PIEDMONT 156. 149. WINDERMERE 83. 78. SUWANNEE RV 78. 75. FT WHITE S 78. 74. ATWATER 42. 40. HAVANA 0. 27. TRANSFORMER FLOW REPORT TRANSFORMER CNTL MW MVAR PF TAP TAP RANGE FT WHITE N 230. -FT WHITE 1 -22.7 72.3 -0.2995* 0.9637 1.0983/0.8943 FT WHITE 115. -FT WHITE 1 39.9 -65.4 0.5206* 0.9564 1.0953/0.8961 GINNIE 230. -GINNIE 1 25.4 -9.3 0.9390* 1.0000 1.0684/0.8741 TRANSMISSION LINE FLOW REPORT LINE RATEA RATEB RATEC MVA MW ------ MVAR ----------- FROM TO NET CHG CRYSTAL RVR 500. -BROOKRIDGE2598. 2598. 3637. 340. 324. -103. 41. -62. 0. BROOKRIDGE 500. -LK TARPON 1732. 1732. 2425. 329. 312. -106. 42. -63. 0. CRYSTAL RVR 500. -CENTRAL FL2598. 2598. 3637. 701. 701. -11. -22. -33. 0. CENTRAL FLA 500. -KATHLEEN 750. 750. 1050. 275. 256. -99. 18. -81. 0. CRYST RVR PL230. -LECANTO 677. 813. 948. 124. 122. 19. -21. -2. 0. CRYST RVR PL230. -HOLDER 677. 745. 948. 231. 230. 18. -12. 6. 0. HOLDER 230. -CENTRAL FL 656. 797. 918. 168. 168. 1. 1. 1. 0. HOLDER 230. -ROSS PRAIR 677. 745. 948. 227. 226. 11. -6. 4. 0. ANDERSEN 230. -ROSS PRAIR 637. 637. 892. 155. -155. 5. -5. 0. 0. FT WHITE N 230. -SUWANNEE R 492. 604. 689. 283. -274. 70. -36. 34. 0. FT WHITE S 230. -FT WHITE N1195. 1195. 1673. 329. -297. 143. -142. 1. 0. GINNIE 230. -FT WHITE S 454. 542. 636. 195. -194. 22. -20. 2. 0. NEWBERRY 230. -FT WHITE S 492. 604. 689. 109. -101. 41. -45. -3. 0. CRYST RVR PL230. -KING ROAD 492. 604. 604. 20. -20. 3. -7. -4. 0. SLV_SP_N 230. -MARTIN WES 385. 385. 385. 14. -12. 8. -11. -4. 0. CENTRAL FLA 230. -DALLAS 677. 813. 948. 117. -108. 45. -46. -2. 0. ULMERTON 230. -LK TARPON- 637. 637. 892. 82. -80. 19. -23. -4. 0. ULMERTON 230. -NORTHEAST 677. 813. 948. 158. 147. -57. 57. 0. 0. ULMERTON 230. -NORTHEAST 677. 813. 948. 158. 147. -57. 57. 0. 0. BARTOW 230. -NORTHEAST 425. 460. 595. 2. 2. 0. -38. -37. 0. BARTOW 230. -NORTHEAST 425. 460. 595. 2. 2. 0. -38. -37. 0. BARTOW 230. -NORTHEAST 584. 785. 818. 1. -1. -1. -29. -29. 0. BARTOW 230. -NORTHEAST 584. 785. 818. 1. -1. 1. -30. -29. 0. BARTOW 230. -NORTHEAST 584. 785. 818. 1. -1. 0. -30. -31. 0. BARTOW 115. -40 STREET 64. 82. 90. 35. 21. -28. 10. -18. 0. BARTOW 115. -40 STREET 64. 82. 90. 35. 21. -28. 10. -18. 0. BARTOW 115. -NORTHEAST 82. 103. 115. 35. -21. 28. -35. -7. 0. BARTOW 115. -NORTHEAST 82. 103. 115. 35. -21. 28. -35. -7. 0. LBMP AREA REPORT N AREA NAME LOAD MW MVAR PF LOAD+LOSSES MW PLNT MW MVAR LOSS MW MVAR GEN MW MVAR INT MW MVAR 1 FPL 11824. 3697. 0.9544 12019. 0. 0. 194. 3164. 9039. 1317. -2979. 192. 2 PEF 6106. 1611. 0.9669 6238. 0. 0. 131. 1669. 4546. 610. -1702. -277. 3 FTP 56. 13. 0.9750 56. 0. 0. 0. 1. 4546. 610. -56. 7. 4 GVL 233. 51. 0.9766 235. 0. 0. 2. 19. 165. 0. -70. 23. 5 HST 50. 13. 0.9699 51. 0. 0. 0. 2. 2. -1. -49. -11. 6 JEA 1529. 538. 0.9432 1543. 0. 0. 14. 228. 951. 261. -592. -198. 7 KEY 70. 14. 0.9801 71. 0. 0. 1. 8. 11. 5. -60. 32. 9 LWU 45. 11. 0.9700 45. 0. 0. 0. 2. 6. 7. -39. -6. 10 NSB 48. 12. 0.9700 49. 0. 0. 0. 2. 9. 15. -39. 5. 11 FMPP 1211. 237. 0.9813 1232. 0. 0. 20. 319. 1572. 445. 340. 190. 12 SEC 156. 41. 0.9667 188. 0. 0. 32. 229. 1254. 200. 1066. 55. 15 TAL 273. 81. 0.9591 274. 0. 0. 1. 14. 63. 48. -212. 93. 16 TECO 2200. 681. 0.9553 2232. 0. 0. 32. 466. 2260. 767. 27. 196. 17 VER 88. 18. 0.9800 89. 0. 0. 0. 5. 18. 20. -71. 33. 18 NUG 88. 18. 0.9800 89. 0. 0. 1. 25. 250. 81. 249. 56. 19 RCU 101. 35. 0.9431 101. 0. 0. 0. 9. 52. 0. -49. -29. 21 TCEC 101. 35. 0.9431 101. 0. 0. 0. 25. 145. 139. 145. 114. 26 OSC 0. 0. 1.0000 0. 0. 0. 0. 0. 0. 0. 0. 1. 27 OLEANDER 0. 0. 1.0000 0. 0. 0. 0. 0. 0. 0. 0. 0. 28 CALPINE 0. 0. 1.0000 0. 0. 0. 0. 0. 150. -10. 150. -10. 31 VAN 0. 0. 1.0000 0. 0. 0. 0. 0. 0. 0. 0. 0. 33 HPS 0. 0. 1.0000 1. 0. 0. 1. 43. 242. 75. 241. 38.


36 DESOTOGN 0. 0. 1.0000 0. 0. 0. 0. 0. 0. 0. 0. 0. 38 IPP-REL 0. 0. 1.0000 0. 0. 0. 0. 0. 0. 0. 0. 0. AREA TOTAL 24182. 7108. 0.9594 24614. 0. 0. 432. 6232. 25284. 4589. -3699. 503. LBMP ZONE REPORT LBMP ZONE NAME NUM LOAD MW MVAR PF LOSS MW MVAR ST. PETE 51 333.4 81.3 0.9716 1.1 21.4 SVN SPRINGS 53 383.1 84.2 0.9767 4.9 44.3 INVERNESS 55 149.7 30.4 0.9800 0.5 9.8 LAKE WALES 57 225.1 57.5 0.9689 1.0 4.7 WNTR GARDEN 59 202.2 50.7 0.9699 1.1 6.7 APOPKA 61 245.7 49.9 0.9800 0.6 3.7 JAMESTOWN 63 327.3 100.4 0.9560 1.1 9.4 DELAND 65 186.0 42.4 0.9750 0.2 1.0 MONTICELLO 67 132.8 26.6 0.9805 3.3 14.7 OCALA 69 0.0 0.0 0.1 0.3 MONTICEL 71 0.0 0.0 0.1 0.6 PEF GENS 90 87.7 58.9 0.8302 5.9 437.2 COGENS 92 10.6 6.1 0.8666 0.4 11.2 NOLOAD 100 16.0 3.0 0.9824 101.2 984.9 BUSHNELL 281 3.0 0.7 0.9746 0.0 0.0 LEESBURG 282 61.3 13.0 0.9783 0.2 2.6 OCALA 283 160.9 31.0 0.9820 0.3 5.9 NW 301 479.2 118.4 0.9708 14.0 66.4 NORTHEST 302 335.0 124.0 0.9378 6.2 20.7 CENTRAL 303 1109.0 147.0 0.9913 18.6 131.5 KAMO 304 100.8 90.6 0.7438 9.1 33.1 SUMTER 305 419.4 84.6 0.9803 1.1 2.8 SHO-ME 306 984.4 250.3 0.9692 18.2 107.3 M&A 307 532.9 178.0 0.9485 12.3 59.1 TRI-CNTY 308 36.4 10.4 0.9618 0.0 0.1 WTHLCHEE 309 551.2 179.5 0.9508 0.4 1.6 GORDONSV 363 821.8 243.1 0.9589 11.8 148.5 VALLEY 364 986.9 379.9 0.9333 9.8 184.9 436 7.5 0.6 0.9963 0.0 0.0 ZONE-TOTAL LOAD & LOSS MW AND PF 8889.0 223.6 0.9643

OCTOBER 2012. SIS ANCLOTE PHASE I PROJECT TRANSIENT STABILITY REPORT II-1

APPENDIX II Plant and Additional Models

PLANT MODELS

REPORT FOR ALL MODELS BUS 3753 [ANCLOTE STMA22.000] MODELS ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 3753 ANCLOTE STMA 22.000 1 5648-5661 1577-1582 MBASE Z S O R C E X T R A N GENTAP 618.0 0.00400+J 0.20500 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 3.90 0.060 0.50 0.060 2.20 0.00 1.7000 1.6400 0.2650 0.4550 0.2050 0.1450 S(1.0) S(1.2) 0.0878 0.4026 ** IEEET1 ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S VAR 3753 ANCLOTE STMA 22.000 1 12971-12984 4679-4682 1392 TR KA TA VRMAX VRMIN KE TE KF TF SWITCH 0.020 50.00 0.060 4.732 -4.732 0.000 0.635 0.101 1.007 0.0 E1 S(E1) E2 S(E2) KE VAR 2.6250 0.0450 3.5000 0.3520 0.2440 -------------------------------------------------------------------------------- REPORT FOR ALL MODELS BUS 93755 [ANCLOTE CTA119.000] MODELS ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 93755 ANCLOTE CTA1 19.000 1 115549-115562 46574-46579 MBASE Z S O R C E X T R A N GENTAP 318.0 0.00194+J 0.23230 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 7.14 0.047 0.79 0.073 6.26 0.00 1.5132 1.4931 0.3079 0.4671 0.2323 0.1918 S(1.0) S(1.2) 0.1250 0.3770 ** PSS2B ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S V A R S I C O N S 93755 ANCLOTE CTA1 19.000 1 115591-115613 46592-46608 67286-67289 14933-14938 IC1 REMBUS1 IC2 REMBUS2 M N 1 0 3 0 5 1 TW1 TW2 T6 TW3 TW4 T7 KS2 KS3 10.000 10.000 0.000 10.000 0.000 10.000 0.800 1.000 T8 T9 KS1 T1 T2 T3 T4 T10 T11 0.600 0.120 20.000 0.140 0.014 0.140 0.014 0.000 0.000 VS1MAX VS1MIN VS2MAX VS2MIN VSTMAX VSTMIN 0.500 -0.500 2.000 -2.000 0.100 -0.100 ** ST6B ** BUS X-- NAME --X BASEKV MC C O N S I C O N S T A T E S V A R S 93755 ANCLOTE CTA1 19.000 1 115660-115675 14951 46643-46646 67298-67300 OEL OPTION 0 TR KPA KIA KDA TDA VAMAX VAMIN 0.0120 19.1000 47.7000 0.0000 0.0000 5.1000 -4.1000 KFF KM KCI KLR ILR VRMAX VRMIN 1.0000 1.0000 1.0000 30.0000 3.7400 5.1000 -4.1000 KG TG 1.0000 0.0200 ** USGT8H ** BUS X-- NAME --X BASEKV MC I C O N S C O N S S T A T E S V A R S 93755 ANCLOTE CTA1 19.000 1 14954-14957 115708-115741 46655-46661 67307-67325 LS LOGIC FLAG LS1 LOGIC VALUE 0 0 dP LOGIC VALUE LS2 LOGIC VALUE 0 0 BLA BLB KL KS KP DRL 0.9842 0.1842 12.00 7.000 0.1000E-01 20.00 DRS TLT Kpsh TDT PLS TN 20.00 0.6500E-01 1.000 0.1000 0.1000 0.1000


PPR YLO FA KCC TCC PGB 0.6727 0.7500E-01 0.6000 1.250 1.100 0.4659 PUP PLO PGS PGFUP PGFDOWN 0.9439 0.4124 0.5000E-03 0.3000E-01 0.3000E-01 PGTA PGTB TRATE Dup Dlo 1.189 -0.1890 300.4 0.9000E-02 -0.5000E-02 Pgup Pglo Plsm TdP Tdel 0.5000E-03 -0.5000E-03 0.4000 2.000 1.000 Slaw 0.7000E-03 -------------------------------------------------------------------------------- REPORT FOR ALL MODELS BUS 93756 [ANCLOTE CTA219.000] MODELS ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 93756 ANCLOTE CTA2 19.000 1 115563-115576 46580-46585 MBASE Z S O R C E X T R A N GENTAP 318.0 0.00194+J 0.23230 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 7.14 0.047 0.79 0.073 6.26 0.00 1.5132 1.4931 0.3079 0.4671 0.2323 0.1918 S(1.0) S(1.2) 0.1250 0.3770 ** PSS2B ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S V A R S I C O N S 93756 ANCLOTE CTA2 19.000 1 115614-115636 46609-46625 67290-67293 14939-14944 IC1 REMBUS1 IC2 REMBUS2 M N 1 0 3 0 5 1 TW1 TW2 T6 TW3 TW4 T7 KS2 KS3 10.000 10.000 0.000 10.000 0.000 10.000 0.800 1.000 T8 T9 KS1 T1 T2 T3 T4 T10 T11 0.600 0.120 20.000 0.140 0.014 0.140 0.014 0.000 0.000 VS1MAX VS1MIN VS2MAX VS2MIN VSTMAX VSTMIN 0.500 -0.500 2.000 -2.000 0.100 -0.100 ** ST6B ** BUS X-- NAME --X BASEKV MC C O N S I C O N S T A T E S V A R S 93756 ANCLOTE CTA2 19.000 1 115676-115691 14952 46647-46650 67301-67303 OEL OPTION 0 TR KPA KIA KDA TDA VAMAX VAMIN 0.0120 19.1000 47.7000 0.0000 0.0000 5.1000 -4.1000 KFF KM KCI KLR ILR VRMAX VRMIN 1.0000 1.0000 1.0000 30.0000 3.7400 5.1000 -4.1000 KG TG 1.0000 0.0200 ** USGT8H ** BUS X-- NAME --X BASEKV MC I C O N S C O N S S T A T E S V A R S 93756 ANCLOTE CTA2 19.000 1 14958-14961 115742-115775 46662-46668 67326-67344 LS LOGIC FLAG LS1 LOGIC VALUE 0 0 dP LOGIC VALUE LS2 LOGIC VALUE 0 0 BLA BLB KL KS KP DRL 0.9842 0.1842 12.00 7.000 0.1000E-01 20.00 DRS TLT Kpsh TDT PLS TN 20.00 0.6500E-01 1.000 0.1000 0.1000 0.1000 PPR YLO FA KCC TCC PGB 0.6727 0.7500E-01 0.6000 1.250 1.100 0.4659 PUP PLO PGS PGFUP PGFDOWN 0.9439 0.4124 0.5000E-03 0.3000E-01 0.3000E-01 PGTA PGTB TRATE Dup Dlo 1.189 -0.1890 300.4 0.9000E-02 -0.5000E-02 Pgup Pglo Plsm TdP Tdel 0.5000E-03 -0.5000E-03 0.4000 2.000 1.000 Slaw 0.7000E-03 ------------------------------------------------------------------------------- REPORT FOR ALL MODELS BUS 93757 [ANCLOTE CTA319.000] MODELS ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 93757 ANCLOTE CTA3 19.000 1 115577-115590 46586-46591


MBASE Z S O R C E X T R A N GENTAP 318.0 0.00194+J 0.23230 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 7.14 0.047 0.79 0.073 6.26 0.00 1.5132 1.4931 0.3079 0.4671 0.2323 0.1918 S(1.0) S(1.2) 0.1250 0.3770 ** PSS2B ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S V A R S I C O N S 93757 ANCLOTE CTA3 19.000 1 115637-115659 46626-46642 67294-67297 14945-14950 IC1 REMBUS1 IC2 REMBUS2 M N 1 0 3 0 5 1 TW1 TW2 T6 TW3 TW4 T7 KS2 KS3 10.000 10.000 0.000 10.000 0.000 10.000 0.800 1.000 T8 T9 KS1 T1 T2 T3 T4 T10 T11 0.600 0.120 20.000 0.140 0.014 0.140 0.014 0.000 0.000 VS1MAX VS1MIN VS2MAX VS2MIN VSTMAX VSTMIN 0.500 -0.500 2.000 -2.000 0.100 -0.100 ** ST6B ** BUS X-- NAME --X BASEKV MC C O N S I C O N S T A T E S V A R S 93757 ANCLOTE CTA3 19.000 1 115692-115707 14953 46651-46654 67304-67306 OEL OPTION 0 TR KPA KIA KDA TDA VAMAX VAMIN 0.0120 19.1000 47.7000 0.0000 0.0000 5.1000 -4.1000 KFF KM KCI KLR ILR VRMAX VRMIN 1.0000 1.0000 1.0000 30.0000 3.7400 5.1000 -4.1000 KG TG 1.0000 0.0200 ** USGT8H ** BUS X-- NAME --X BASEKV MC I C O N S C O N S S T A T E S V A R S 93757 ANCLOTE CTA3 19.000 1 14962-14965 115776-115809 46669-46675 67345-67363 LS LOGIC FLAG LS1 LOGIC VALUE 0 0 dP LOGIC VALUE LS2 LOGIC VALUE 0 0 BLA BLB KL KS KP DRL 0.9842 0.1842 12.00 7.000 0.1000E-01 20.00 DRS TLT Kpsh TDT PLS TN 20.00 0.6500E-01 1.000 0.1000 0.1000 0.1000 PPR YLO FA KCC TCC PGB 0.6727 0.7500E-01 0.6000 1.250 1.100 0.4659 PUP PLO PGS PGFUP PGFDOWN 0.9439 0.4124 0.5000E-03 0.3000E-01 0.3000E-01 PGTA PGTB TRATE Dup Dlo 1.189 -0.1890 300.4 0.9000E-02 -0.5000E-02 Pgup Pglo Plsm TdP Tdel 0.5000E-03 -0.5000E-03 0.4000 2.000 1.000 Slaw 0.7000E-03 --------------------------------------------------------------------------------

LOAD MODELS REPORT FOR ALL MODELS BUS 3753 [ANCLOTE STMA22.000] MODELS ** CLODAR ** BUS X-- NAME --X BASEKV LD C O N S S T A T E S V A R S PRIVATE ICON AREA 2 3753 ANCLOTE STMA 22.000 1 115409-115416 45144-45145 47252-47279 14166 PC-LM PC-SM PC-TX PC-DL PC-CP KP R X 23.00 0.00 0.00 30.00 0.00 2.000 0.0100 0.0600 -------------------------------------------------------------------------------- REPORT FOR ALL MODELS BUS 93755 [ANCLOTE CTA119.000] MODELS ** CLODAR ** BUS X-- NAME --X BASEKV LD C O N S S T A T E S V A R S PRIVATE ICON AREA 2 93755 ANCLOTE CTA1 19.000 1 115409-115416 45686-45687 54840-54867 14437 PC-LM PC-SM PC-TX PC-DL PC-CP KP R X 23.00 0.00 0.00 30.00 0.00 2.000 0.0100 0.0600 -------------------------------------------------------------------------------- REPORT FOR ALL MODELS BUS 93756 [ANCLOTE CTA219.000] MODELS ** CLODAR ** BUS X-- NAME --X BASEKV LD C O N S S T A T E S V A R S PRIVATE ICON AREA 2 93756 ANCLOTE CTA2 19.000 1 115409-115416 45688-45689 54868-54895 14438


PC-LM PC-SM PC-TX PC-DL PC-CP KP R X 23.00 0.00 0.00 30.00 0.00 2.000 0.0100 0.0600 -------------------------------------------------------------------------------- REPORT FOR ALL MODELS BUS 93757 [ANCLOTE CTA319.000] MODELS ** CLODAR ** BUS X-- NAME --X BASEKV LD C O N S S T A T E S V A R S PRIVATE ICON AREA 2 93757 ANCLOTE CTA3 19.000 1 115409-115416 45690-45691 54896-54923 14439 PC-LM PC-SM PC-TX PC-DL PC-CP KP R X 23.00 0.00 0.00 30.00 0.00 2.000 0.0100 0.0600

CONET MODELS *** CALL MAOS ( 10586,115359, 0, 0) *** ICONS CONS 10586- 10587 115359-115360 OVERSPEED RELAYS OR MAX ANGLE ENABLED TRIP FREQUENCY - TRIP MAX ANGLE - AREAS TO SKIP 63.00 181.00 30 - 25

OCTOBER 2012. SIS ANCLOTE PHASE I PROJECT TRANSIENT STABILITY REPORT III-1

APPENDIX III Contingency Model Descriptions

III-1 Contingency Descriptions III-2 Shunt Admitance

The naming of the contingencies follows the format:

XXXX ### Where: XXXX: Four letters identifying the substation name or three letters and a number to identify voltage level ###: Three digit number identifying the type of fault 300 Series: Category D Contingencies 200 Series: Category C Contingencies 100 Series: Category B Contingencies 10 Series: Contingency number


III-1 Contingency Description

ALDM309 3-PHASE FAULT AT ALDERMAN 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS ANCL101 3PH @ ANCLOTE - SEVS 23OKVCLEAR CFLA 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ ANCL102 3PH @ ANCLOTE-GULF PINE 230KVCLEAR ANDR 69KV CLEAR CLEAR LOCAL @4.0~, REMOTE @4.5~ ANCL103 3PH @ANCLOTE-E.CLEARWATER 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ ANCL200 SLG-NBKR4 STUCK@ANCLOTE PLANT 230KV (NON-IPT) CLEAR ANCL @4~, BFBU @9.9~ ANCL209 SLG FAULT ANCLOTE 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS ANCL300 3PH-NBKR4 STUCK@ANCLE PLANT 230KV (NON-IPT) CLEAR ANCL @4~, BFBU @9.9~ ANCL301 3PH-4352 STUCK@ANCLE PLANT 230KV (NON-IPT) CLEAR G2 OVSP, BFBU @10~, SEVS @11~ ANCL301 3PH-4352 STUCK@ANCLE PLANT 230KV (NON-IPT) CLEAR G2 OVSP, BFBU @10~, SEVS @30~ ANCL302 3PH @ ANCLOTE - SEVS 23OKV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ ANCL303 3PH @ ANCLOTE-LARGO 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ ANCL309 3-PHASE FAULT ANCLOTE 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS ANCL310 LOSS OF SUBSTATION + XFMRS ANCLOTE 230 KV ANCL311 LOSS OF ANCLOTE GENERATION STATION BKR1303r 3PH-3644 STUCK @BROOKRIDGE 115KV (NON-IPT) CLEAR HMMK @5~, BFBU @17~, BKVW @18~ BKR2301r 3PH-4921 STUCK @BROOKRIDGE 230KV (NON-IPT) CLEAR T3 @4~, BFBU @11~, BKVW @12~ BKRG301t 3PH-5132 STK@BROOKRIDGE 500KV (IPT) CLEAR T2 @4~, BFBU @9.5~, LTPN @10.5~ BKV1303r 3PH-B1119 STUCK @ BROOKSVILLE WEST 115KV (NON-IPT) CLEAR BKVL @5~, BFBU @17~, BKRG @18~ BKVW301r 3PH-B1105 STUCK @ BROOKSVILLE WEST 230KV (NON-IPT) CLEAR T2 @4~, BFBU @13~, BKRG @14~ CFL2301tr 3PH-1914 STUCK @ CENTRAL FLA 230KV (NON IPT) CLEAR CFL2 @4~, BFBU-T2 @11~ CFLA301t 3PH-5114 STK@CENTRAL FLORIDA 500KV (IPT) CLEAR T2 @4~, BFBU @11~, CRP5 @12~ CIT2301 3PH-2227 STUCK @ CYTRUS 230KV (NON-IPT) CLEAR CRPL 4.5~, BFBU @12~, HOLD @12.5~ CRP5302a 3PH-1660 STK@CRYSTAL RIVER 500KV (IPT) CLEAR BKRG @3~, BFBU @8~, G5 OVSP CRPL301 3PH-3234 STUCK@CR RV PLANT 230KV (NON-IPT) CLEAR SS XFMER @4~, BFBU @8.5~, G4 OVSP CRPL310 LOSS SUBSTATION PLUS XFMRS CRYSTAL RIVER ENERGY COMPLEX CRPL311 LOSS OF CRYSTAL RIVER GENERATION STATION CURL309 3-PHASE FAULT AT CURLEW 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS ECL1209 SLG FAULT AT E CLEARWATER 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS ECL1309 3-PHASE FAULT AT E CLEARWATER 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS ECLW200 SLG 1470 [email protected] 230KV (NON-IPT) CLEAR XFMER @6~, BFBU @14~, ULMR @15~

ECLW209 SLG FAULT E CLEARWATER 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM THE REMOTE ENDS ECLW300 3PH 1470 [email protected] 230KV (NON-IPT) CLEAR XFMER @6~, BFBU @14~, ULMR @15~ ECLW301 3PH 1472 [email protected] 230KV (NON-IPT) CLEAR LTPN @4~, BFBU @14~, ANCL @15~ ECLW302 3PH 1478 [email protected] 230KV (NON-IPT) CLEAR XFMER @5~, BFBU @14~, ULMR @15~ ECLW303 3PH @E.CLEARWATER-ULMERTON 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ ECLW309 3-PHASE FAULT E CLEARWATER 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM THE REMOTE ENDS ELFR309 3-PHASE FAULT ELFERS 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS FLMR303 3PH @FLORAMAR - SEVEN S 115KV (RF) LOCAL @4.0~, REMOTE @30~ GULF101 3PH @GULF PINE-ANCLOTE 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ GULF102 3PH @GULF PINE-HUDSON 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ GULF103 3PH @GULF PINE-LAKE TARPON 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ GULF201 3PH @GULF PINE-LAKE TARPON 230KV (DCT) CLEAR LOCAL @4.0~, REMOTE @4.5~ GULF209 SLG FAULT GULF PINE 230KV BUS (RF) CLEAR IN Z2 FROM REMOTE ENDS GULF300 3PH-N4 STUCK@GULF PINE 230KV (NON-IPT) CLEAR BFBU @9~, ANCL @10~ GULF301 3PH-N3 STUCK@GULF PINE 230KV (NON-IPT) CLEAR BKVW @4~, BFBU @9~, SEVS @10~ GULF301 3PH-N3 STUCK@GULF PINE 230KV (NON-IPT) CLEAR BKVW @4~, BFBU @9~, SEVS @30~ GULF302 3PH-N1 STUCK@GULF PINE 230KV (NON-IPT) CLEAR LTPN @4~, BFBU @9~, SEVS @10~ GULF303 3PH @GULF P - SEVEN S 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ GULF304 3PH @GULF P - BROOSVILLEW 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ GULF309 3-PHASE FAULT GULF PINE 230KV BUS (RF) CLEAR IN Z2 FROM REMOTE ENDS HOLD303 3PH-2624 STUCK @ HOLDER 230kV (NON-IPT) CLEAR XFMER @6~, BFBU @14, CRPL @14.5~ HUD1209 SLG FAULT AT HUDSON 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS HUD1209N SLG FAULT AT HUDSON 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS HUD1300 3PH-6648 STUCK @HUDSON 115KV (NON-IPT) CLEAR BFBU @17~, NWPR @35~ HUD1301 3PH-2635 STUCK @HUDSON 115KV (NON-IPT) CLEAR BFBU @17~, BKVW @35~ HUD1301 3PH-2636 STUCK @HUDSON 115KV (NON-IPT) CLEAR XFMER @4~, BFBU @17~, BKVW @35~ HUD1309 3-PHASE FAULT HUDSON 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS HUDS101 3PH @HUDSON-GULF PINE 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ HUDS201 SLG 2515 STUCK@HUDSON 230KV (NON-IPT) CLEAR XFMER @5~, BFBU @14~, BKRG @30~ HUDS209 SLG FAULT AT HUDSON 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS


HUDS300 3PH 2519 STUCK@HUDSON 230KV (NON-IPT) CLEAR XFMER @5~, BFBU @15~, SHDY @30~ HUDS301 3PH 2515 STUCK@HUDSON 230KV (NON-IPT) CLEAR XFMER @5~, BFBU @12~, BKRG @30~ HUDS302N 3PH 2516 STUCK@HUDSON 230KV (NON-IPT) CLEAR XFMER @5~, BFBU @12~, GULF @30~ HUDS303 3PH @HUDSON-SHADY HILLS 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ HUDS304 3PH @HUDSON-BROOKRIDGE 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ HUDS309 3-PHASE FAULT AT HUDSON 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS LRGO101 3PH @LARGO-ANCLOTE 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ LRGO200 SLG-3130 STUCK@LARGO 230KV (NON-IPT) CLEAR XFMER @6~, BFBU @15~, ULMR @16~ LRGO209 SLG FAULT LARGO 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS LRGO300 3PH-3130 STUCK@LARGO 230KV (NON-IPT) CLEAR XFMER @6~, BFBU @15~, ULMR @16~ LRGO301 3PH-3134 STUCK@LARGO 230KV (NON-IPT) CLEAR SMNL @4~, BFBU @15~, ANCL @16~ LRGO303 3PH @LARGO-ULMERTON 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @35~ LRGO309 3-PHASE FAULT LARGO 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS LROW301 LOSS OF R/W EAST OF ANCLOTE LROW302 LOSS OF R/W SOUTH OF CRYSTAL RIVER LROW303 LOSS OF R/W SOUTH OF BROOKRIDGE LROW304 LOSS OF R/W NORTH OF LAKE TARPON LTP2101N 3PH @ LK TARPON-GULF PINE 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ LTP102 3PH @ LK TARPON-SHELDON 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ LTP2200 SLG-4549 STUCK @ LK TARPON 230KV (NON IPT) CLEAR T2 @4~, BFBU @9~, SHEL @10~ LTP2209 SLG FAULT AT LAKE TARPON 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM THE REMOTE ENDS LTP2300 3PH-4549 STUCK @ LK TARPON 230KV (NON IPT) CLEAR T2 @4~, BFBU @9~, SHEL @10~ LTP2301 3PH-1861 STUCK @ LK TARPON 230KV (NON IPT) CLEAR PMHR @4~, BFBU @10~, GULF @11~ LTP2302 3PH-1858 STUCK @ LK TARPON 230KV (NON IPT) CLEAR ULMR @4~, BFBU @10~, GULF @11~ LTP2304 3PH @ LK TARPON-SHELDON RD 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @35~ LTP2305 3PH @ LK TARPON-HIGGINS 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @35~ LTP2309 3-PHASE FAULT AT LAKE TARPON 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM THE REMOTE ENDS LTPN101 3PH @LAKE TARPON-BROOKRIDGE 500KV CLEAR LOCAL @3.0~, REMOTE @3.5~ LTPN209 SLG FAULT AT LAKE TARPON 500KV BUS (RF) CLEAR IN ACTUAL TIMES FROM THE REMOTE ENDS LTPN301 3PH-4619 STK@LAKE TARPON 500KV (IPT) CLEAR T1 @4~, BFBU @10.2~, BKRG @11.2~ LTPN309 3-PHASE FAULT AT LAKE TARPON 500KV BUS (RF) CLEAR IN ACTUAL TIMES FROM THE REMOTE ENDS NWPR309 3-PHASE FAULT NEW PT RICHY 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM THE REMOTE ENDS PMHR209 SLG FAULT PALM HARBOR 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM THE REMOTE ENDS

PMHR309 3-PHASE FAULT PALM HARBOR 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS SEV1101 3PH @SEVEN S - P RICHEY W 115KV CLEAR LOCAL @4.0~, REMOTE @4.5~ SEV1102 3PH @SEVEN S - FLORAMAR 115KV CLEAR LOCAL @4.0~, REMOTE @4.5~ SEV1209 SLG FAULT 7 SPRINGS 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS SEV1300 3PH-4680 STUCK @SEVEN SPRINGS 115KV CLEAR SEVS @4~, BFBU @15~, XMFER @16~ SEV1301 3PH-2722 @SEVEN SPRINGS 115KV CLEAR XFMER @4~, BFBU @15~, PTRW @16~ SEV1301L 3PH-2722 @SEVEN SPRINGS 115KV CLEAR XFMER @4~, BFBU @15~, PTRW @30~ SEV1302 3PH-2012 @SEVEN SPRINGS 115KV CLEAR XFMER @4~, TPNS @5~, BFBU @15 SEV1303 3PH @SEVEN S - FLORAMAR 115KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ SEV1309 3-PHASE FAULT 7 SPRINGS 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS SEVS101 3PH @ SEVS-ANCLOTE 230KV CLEAR LOCAL @4.0~, REMOTE @4.5~ SEVS201 SLG-2738 STUCK @ SEVS 230KV CLEAR XFMER @4~, BFBU @11~, GULF @12~ SEVS209 SLG FAULT 7 SPRINGS 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS SEVS300 3PH-2005 STUCK @ SEVS 230KV CLEAR XFMER @4~, BFBU @11~, ANLC @12~ SEVS301 3PH-2738 STUCK @ SEVS 230KV CLEAR XFMER @4~, BFBU @11~, GULF @12~ SEVS301L 3PH-2738 STUCK @ SEVS 230KV CLEAR XFMER @4~, BFBU @11~, GULF @30~ SEVS302 3PH @ SEVS-GULF PINE 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ SEVS303 3PH @ SEVS-ANCLOTE 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ SEVS309 3-PHASE FAULT 7 SPRINGS 230KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS SHEL301 3PH @ SHELDON-JENUEU 230KV CLEAR LOCAL @5.0~, REMOTE @5.5~ SHEL201 SLG-??? STUCK@SHELDON 230KV BUS (NON-IPT) CLEAR JKSRD @6~, BFBU @16~, JNEU @17~ SHEL204 SLG @ SHELDON RD-LK TARPON 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @35~ SHEL209 SLG FAULT AT SHELDON 230KV BUS (RF) CLEAR IN Z3 (60~) FROM REMOTE ENDS SHEL301 3PH-??? STUCK@SHELDON 230KV BUS (NON-IPT) CLEAR JKSRD @6~, BFBU @16~, JNEU @17~ SHEL304 3PH @ SHELDON RD-LK TARPON 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @35~ SHEL309 3-PHASE FAULT AT SHELDON 230KV BUS (RF) CLEAR IN Z3 (60~) FROM REMOTE ENDS TPNS209 SLG FAULT TARPON SPNGS 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS TPNS309 3-PHASE FAULT TARPON SPNGS 115KV BUS (RF) CLEAR IN ACTUAL TIMES FROM REMOTE ENDS ULMR204 SLG @ULMERTON-LARGO 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ ULMR303 3PH @ULMERTON-E.CLEARWATER 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~ ULMR304 3PH @ULMERTON-LARGO 230KV (RF) CLEAR LOCAL @4.0~, REMOTE @30~


III-2 Shunt Admitance

AREA BUS NAME BUS NO SLG-SHUNT MVA 2 ALDERMAN 115. 2241 206. -993. 2 CURLEW 115. 2243 179. -1009. 2 E CLRWTR 115. 2244 288. -2168. 2 HIGGINS 115. 2245 292. -2402. 2 OLDSMAR 115. 2247 151. -878. 2 SAFETY H 115. 2248 266. -1778. 2 GRIFFIN 115. 2249 93. -992. 2 E CLRWTR 230. 2267 504. -4015. 2 HIGGINS 230. 2268 391. -2953. 2 LKTRPN-A 230. 2269 677. -7389. 2 PALM HBR 230. 2270 337. -2545. 2 GRIFFIN 230. 2271 345. -2584. 2 LKTRPN-B 230. 2272 677. -7389. 2 GULF PINE 230. 2280 524. -3086. 2 LK TARPN 500. 2288 -3. -5612. 2 LECANTO 115. 3447 115. -587. 2 BRKRIDGE 115. 3450 264. -2723. 2 BRKSVL W 115. 3451 294. -2902. 2 HMMCK2TP 115. 3452 222. -949. 2 BROOKSVL 115. 3453 40. -194. 2 CRYST RE 115. 3456 128. -1286. 2 CRYST RN 115. 3457 137. -551. 2 CRYST RS 115. 3458 151. -699. 2 CRYSTLTP 115. 3459 135. -653. 2 HAMMCKTP 115. 3463 217. -873. 2 HAMMCK 115. 3464 134. -484. 2 HOLDER 115. 3465 85. -949. 2 BRKRIDGE 230. 3518 487. -4396. 2 BRKSVL W 230. 3519 318. -2762. 2 BRKSVWTP 230. 3520 395. -3348. 2 CENT FLA 230. 3521 457. -4597. 2 CR PLANT 230. 3522 404. -7999. 2 CRYST RE 230. 3523 476. -2781. 2 CRYST R4 230. 3524 398. -7817. 2 HOLDER 230. 3527 258. -2137. 2 BRKRIDGE 500. 3550 -76. -5874. 2 CENT FLA 500. 3551 421. -4902. 2 CRYST RV 500. 3555 288. -7040. 2 CRYST R5 500. 3556 288. -7040. 2 PASADENA 230. 3705 319. -1806. 2 HUDSONSW 115. 3800 174. -846. 2 HUDSONTP 115. 3801 144. -888. 2 ELFERS 115. 3804 333. -1215. 2 FLORAMAR 115. 3805 210. -900. 2 HUDSN 115. 3806 282. -2559. 2 NPT RCHY 115. 3809 198. -1045. 2 P RICHYW 115. 3810 173. -737. 2 HUDSON2 115. 3818 282. -2559. 2 ANCLOTE 230. 3834 410. -6239. 2 HUDSN 230. 3836 433. -3150. 2 SEVEN SP 230. 3837 518. -3248. 2 SHADYHLS 230. 3839 426. -3013. 2 ULMERTON 115. 3911 309. -2429. 2 LARGO 230. 3930 458. -3323. 2 SMNLE 230. 3931 323. -1915. 2 ULMERTON 230. 3932 707. -4764. 2 HUDSON 115. 7075 175. -845. 2 NP RICHY 115. 7077 198. -1011. 2 CURLEY 115. 7113 58. -385. 2 SPG HL 3 115. 7115 4. -115.

OCTOBER 2012. SIS ANCLOTE PHASE I PROJECT TRANSIENT STABILITY REPORT IV-1

APPENDIX IV Transient Stability Result Plots

THIS APPENDIX

IS

AVAILABLE IN A SEPARATE VOLUME

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PROVIDED UPON REQUEST

Documents

SYSTEM IMPACT STUDY FOR THE ANCLOTE REPOWERING … · 2019-12-19 · 1. LRS Pass 5 case 2. Two 1120 MVA autos at CFLA (already in case) 3. Existing Anclote Units @ max 4. Bartow,