Facility
Connection
Requirements
OCTOBER 2004
Progress
Energy
6565 –
(727)
820-5151
A Progress Energy Company
Facility
Connection
Requirements
OCTOBER 2004
Progress
Energy
6565 –
(727)
820-5151
A Progress Energy Company
Progress Energy
Facility Connection Requirements
Table of
Contents
I.
General
Requirements
A.
Definitions
B.
Responsibilities
C.
Planning Standards
D.
Design Standards
E.
Design Review
F.
Reliability and System Security
G.
Future Modifications
H.
Operating Standards
I.
Transmission Service
II.
Generation
Facility Connection Requirements
A.
Overview
B.
Applicability
C.
Process
D.
Generation Interconnection Technical Requirements
III.
Transmission Facility
Connection Requirements
A.
Overview
B.
Applicability
C.
Process
D.
Transmission Interconnection Technical Requirements
IV.
End User Facility Connection
Requirements
A.
Process
B.
End User Interconnection Technical Requirements
Appendix A: PEF Design Specifications
Appendix B: PEF Generation Interconnection Study Data
Request Form
Appendix C: PEF Substation Bus Voltage Schedules
Appendix D: PEF Electrical Facility Ratings
PEF Facility Connection Requirements
I.
General
Requirements
A.
Definitions
1.
“PEF” stands for Progress Energy
2.
The term “Customer” means a requestor of a generation,
transmission, or
end-use interconnection to the PEF Transmission System.
3. The term “Party” or
“Parties” means Customer and PEF individually or collectively.
4.
The term “System” means the PEF Transmission System.
5.
“FRCC” stands for Florida Reliability Coordinating
Council.
6.
“NERC” stands for North American Electric Reliability
Council.
7.
“Point of Receipt” means the point of interconnection
to the System for new generation, transmission, or end- user facilities.
8. “OATT”
stands for Open
Access Transmission Tariff.
9.
The term “Interconnection Facilities” refers to
transmission additions or upgrades necessary to directly interconnect
generation to the System.
10. The
term “Required System Upgrades” refers
to transmission additions or upgrades necessary for the safe and reliable
interconnection of generation to the System.
B.
Responsibilities
The Parties
shall each assume responsibility for its own transmission and substation
facilities connected to the System as specified in the Generation or Transmission
Interconnection Agreement. The recommendations
made by PEF in this document shall not relieve the Customer from complete
responsibility for the adequate engineering design, construction and operation
of the Customer’s equipment or from any liability for injuries to property or
persons associated with any failure to perform in a proper and safe manner for
any reasons.
C. Planning Standards
The Customer shall comply with all NERC Planning Standards and associated Measurements as these are adopted through the NERC “Due Process,” and FRCC Standards which are applicable to generation and/or transmission owners.
D. Design Standards
Customer-owned transmission and substation facilities used to interconnect new generation, transmission, or end use to the System shall be designed to meet all applicable NESC, Florida State and County construction codes, as well as comply with the PEF Table of Specifications attached hereto as Appendix A.
E. Design
Review
PEF shall review the design of Customer-owned transmission and substation facilities connected to the System prior to construction. If in PEF’s sole judgment, the design of transmission and/or substation facilities would impair the reliability to the PEF system, the Parties shall agree to necessary design changes prior to the start of construction.
F. Reliability
and System Security
The Parties
shall follow
guidelines specified by the FRCC and the NERC for planning a reliable and
secure transmission system.
G. Future
Modifications
Any change
in the Customer’s transmission and substation facilities interconnected to the
System made subsequent to the in-service date of the generation, transmission,
or end use interconnection to the System must be submitted to PEF for review
prior to the actual modification.
H.
Operating
Standards
The parties
shall comply with the manuals, standards and guidelines of NERC and FRCC
related to the operation and reliability of the transmission grid. Each Party shall provide to the other Party
information reasonably necessary to comply with such manuals, standards and
guidelines and shall operate the respective facilities in accordance with the
manuals, standards and guidelines.
I.
Transmission
Service
The
interconnection process outlined in this document is separate from the process
of requesting and reserving transmission service. The procedure for requesting and reserving
transmission service on the System is set forth in the OATT. A Customer interconnecting generation or
transmission to the System receives no explicit or implied Available
Transmission Transfer Capability (i.e. ATC) on the System by executing a
Generation Interconnection and Operating Agreement or Transmission
Interconnection Agreement with PEF. Any
transmission additions or upgrades necessary to provide transmission service to
the Customer shall be based on the specific Transmission Service Request and
pursuant to the terms and conditions of the OATT.
II. Generation
Facility Connection Requirements
A. Overview
This section provides the Customer general technical information, as well as outlines the process for interconnecting generation to the System or evaluating a generation capacity increase at an existing Point of Receipt on the System. Each generation interconnection request shall be separately evaluated by PEF Transmission Planning and affected design engineering groups within PEF.
B. Applicability
This section applies to all generation interconnections to the System or generation capacity increases on the System at 69 kV or greater where generation is installed behind the Point of Receipt and capable of operating in parallel with the System; and applies to PEF generators, co-generators, qualifying facilities, merchant plants, and non-utility generators.
C. Process
The
interconnection of generation to the System or a generation capacity increase
at an existing Point of Receipt on the System will comply with Attachment P,
Standard Large Generator Interconnection Procedures (LGIP) of Open Access
Transmission Tariff of Florida Power Corporation dba Progress Energy
1. Energy
Resource (ER) Interconnection Service
This process
shall be used to process a generation interconnection request that is not being evaluated as a new network
resource on the System (either to serve PEF native load or a PEF network
customer). Energy Resource
Interconnection Service allows the Interconnection Customer to connect the
Large Generating Facility to the Transmission System and be eligible to deliver
the Large Generating Facility’s output using the existing firm or non-firm
capacity of the Transmission System on an “as available” basis. ER Interconnection Service does not in and of
itself convey any transmission service.
The study consists of short circuit/fault
duty, steady state (thermal and voltage) and stability analyses. The short circuit/fault duty analysis would
identify direct Interconnection Facilities required and the Network Upgrades
necessary to address short circuit issues associated with the Interconnection
Facilities. The stability and steady
state studies would identify necessary upgrades to allow full output of the
proposed Large Generating Facility and would also identify the maximum allowed
output, at the time the study is performed, of the interconnecting Large
Generating Facility without requiring additional Network Upgrades.
2. Network
Resource Interconnection Service
The Transmission Provider must conduct the
necessary studies and construct the Network Upgrades needed to integrate the
Large Generating Facility (1) in a manner comparable to that in which the
Transmission Provider integrates its Generating Facilities to serve native load
customers; or (2) in an ISO or RTO with market based congestion management, in
the same manner as all other Network Resources.
NR Interconnection Service Allows the Interconnection Customer 's Large
Generating Facility to be designated as a Network Resource, up to the Large Generating
Facility's full output, on the same basis as all other existing Network
Resources interconnected to the Transmission Provider's Transmission System,
and to be studied as a Network Resource on the assumption that such a
designation will occur.
The Interconnection Study for NR
Interconnection Service shall assure that the Interconnection Customer's Large
Generating Facility meets the requirements for NR Interconnection Service and
as a general matter, that such Large Generating Facility's interconnection is
also studied with the Transmission Provider’s Transmission System at peak load,
under a variety of severely stressed conditions, to determine whether, with the
Large Generating Facility at full output, the aggregate of generation in the
local area can be delivered to the aggregate of load on the Transmission
Provider’s Transmission System, consistent with the Transmission Provider’s
reliability criteria and procedures.
This approach assumes that some portion of existing Network Resources
are displaced by the output of the Interconnection Customer's Large Generating
Facility. NR Interconnection Service in
and of itself does not convey any transmission service.
3. Generation Interconnection and Operating
Agreement
The results of a generation interconnection study shall provide the basis for the Parties to negotiate a Generation Interconnection and Operating Agreement. The scope of the Generation Interconnection and Operating Agreement shall include, without limitation, the following:
·
The responsibility for the design,
construction and placing in service Interconnection Facilities and Required
System Upgrades necessary to interconnect the new generation to the System.
·
The responsibility for payment of costs for
Interconnection Facilities and Required System Upgrades necessary to
interconnect the generation to the System.
·
The allocation of ownership and responsibility
for operation, control and maintenance of Interconnection Facilities and
Required System Upgrades necessary to interconnect the generation to the
System.
·
Operating requirements for generation to operate
in parallel with the System.
·
Establishment of milestone dates for permitting
and construction of a generation interconnection to the System
An approved Generation Interconnection and Operating Agreement between the Customer and PEF is required prior to a generation interconnection going in-service and operating in parallel with the System.
4. Other Agreements
Other agreements that could be required for the Customer to operate in parallel with the PEF system include:
· Retail Service Agreement(s) where applicable
· Momentary Paralleling Agreement where applicable
· Transmission Service Agreement(s) necessary to schedule power out of the generation using the System, including required Ancillary Services.
1. Interconnection Configuration Guidelines
The generation interconnection study shall determine the final configuration that will be used to interconnect the generation to the System based on review of various interconnection alternatives between the Customer and PEF. The final configuration may include a combination of generator leads/step-up transformers and substation/transmission facilities that are necessary to interconnect to the System. PEF recommends that the interconnection to the System be configured so a single outage does not outage more than 500 MW of generation. However, in no case shall a single contingency outage of substation or transmission facilities be permitted to force out more than 850 MW at one time. Depending on the type of generation and the location on the System, the generation interconnection might require a looped transmission connection to the System. In most cases, a transmission line tapped off an existing PEF network transmission line with a generator connected at the end of the tapped line will not meet PEF’s System Protection and Control Standards without a switching substation (i.e. with circuit breakers) at the tap point.
a. Looped Configuration
If the final interconnection configuration specifies looping new lines off an existing PEF network transmission line or looping an existing PEF network transmission line into a Customer generation and/or switching substation, PEF shall own, operate, control and maintain:
· The transmission line segments looped off an existing PEF network transmission line. These line segments shall meet PEF Transmission Design Standards. Normal and emergency line ratings shall be determined based on the results of the Feasibility Study. The ratings of the new segments shall have a margin to accommodate uncertainty in operating conditions, system load growth, and the future planned interconnected FRCC Transmission System.
· The section of the Customer generating and/or switching substation including breakers, switches, and other control/metering equipment that affect the continuity of the existing PEF network transmission line. This section of the Customer generating and or switching substation equipment will meet PEF Substation and Relay Design Standards. The Customer generating and/or switching substation shall be configured so that a single contingency on the Customer’s side of the substation does not interrupt the continuity of the existing PEF network transmission line. The ratings of the substation series equipment shall be coordinated between the Parties and shall equal or exceed the rating of the new or existing looped line segments described above.
b. Radial Configuration
For a radial generation interconnection to the System, a single contingency on the Customer’s side of the interconnection shall not outage any PEF transmission line, transformer, or interconnection with an adjoining transmission system or Customer. Customer-owned transmission facilities shall comply with the requirements detailed in Section III of the PEF Facility Connection Requirements. Transmission or substation facilities that must be modified at an PEF substation to accommodate a new radial transmission interconnection shall be designed, owned, operated, controlled, and maintained by PEF.
2. Generation
Operating Characteristics
As an integral part of the PEF
electrical system, the Customer
shall not operate the facility in any manner that will impair PEF's
ability to meet quality of service guidelines established by the Florida
Public Service Commission.
The governor control on the prime mover shall be capable of maintaining the generator output frequency within limits for generator loading from no-load up to rated output. Governor control shall provide a five percent (5%) droop characteristic and shall, as a minimum, be fully responsive to frequency deviations exceeding ± 0.036 Hz (±36 MHz).
The output sine wave distortion shall be deemed acceptable when it does not have a higher root mean square harmonic content than described in IEEE 519 at the interconnection point.
The Customer shall coordinate with,
and receive approval from, PEF for the relaying design and
settings for each Customer
interconnection. Protective
requirements for a Customer's generator shall include,
without limitation, the following:
·
undervoltage
·
overload
·
phase and ground fault protection
·
open circuit
·
phase unbalance and reversal
·
underfrequency
·
loss of source (e.g. transfer trip)
·
coordination and synchronization
·
isolated operating conditions
·
prevention of dead-line reclosing
PEF does not
allow deadline reclosing for any source of Customer generation.
For generators greater than 25 MW, the Customer shall:
· Include with the generator an overexcited power factor capability, measured at the generator terminals, of 0.9 per unit (p.u.) or less and an underexcited power factor capability of 0.95 p.u. or less.
· Include with the generator an overexcited power factor capability, measured at the unit main transformer high voltage terminals (transmission voltage side), of 0.95 p.u. or less and an underexcited power factor capability of 0.95 p.u. or less.
· Include with the generator an Automatic Voltage Regulator (AVR) capable of maintaining the specified generator output voltage within limits for generator loading from no load to up to rated output.
· Coordinate the generator step-up transformer impedance and tap specifications with PEF.
· Maintain the generator AVR setting at the desired voltage level specified by PEF standards. The PEF standard control voltage schedule is found in Appendix C attached hereto.
· Ensure that the full range of generator reactive power capability is available for applicable normal and emergency network voltage ranges.
5. Stability
Generators larger than 100 MW shall have a control system capable of accommodating a power system stabilizer (PSS). A PSS may be required based on the results of the Generation Interconnection Study or at a later date as a result of an PEF or FRCC Stability Study.
6.
Data
Communications
The customer shall provide a 4-wire, full duplex circuit (or circuits) operating at 1200 baud, or at other baud rates as reasonably specified by PEF.
A. Overview
This section provides a Customer general technical information as well as procedural guidelines for interconnecting new transmission facilities to the System. Each transmission interconnection request shall be separately evaluated by PEF Transmission Planning and the affected Design Groups within PEF. The Customer shall execute a Transmission Interconnection Agreement with PEF before constructing a new transmission interconnection to the System. Unless otherwise agreed by the Parties, the Customer shall execute a Transmission Interconnection Agreement and such agreement must be approved by required regulatory authorities before PEF shall add the transmission interconnection to its load flow and stability data bases.
B. Applicability
This section applies to a transmission line interconnection with the System (i.e. voltage 69 kV or greater). This includes a transmission line interconnection between PEF and another FRCC utility or the establishment of a new transmission line interconnection to serve end use Customers on System.
C. Process
The Customer shall use the following process to interconnect new transmission facilities to the System.
1. Initial Contact
The Customer shall submit to the PEF Transmission Planning Department a written transmission interconnection request. The request shall provide sufficient detail for PEF to establish the scope and timing of a transmission interconnection study specific to the request. Specifically, the request shall include, without limitation, the proposed interconnection points with the System or other transmission systems, the required in-service date, and technical details on the intended use of the interconnection.
2. Transmission
Interconnection Study
The Customer may request that PEF perform a Transmission Interconnection Study. The Customer shall execute a Transmission Interconnection Study Agreement and pay to PEF an amount to be negotiated which shall be non-refundable, and which shall be applied to the final cost of the Transmission Interconnection Study. A timeline for completion of the Transmission Interconnection Study shall be agreed to by the Parties, or where the Parties have not agreed, shall be specified by PEF. If the Customer wishes to terminate PEF’s work on the Transmission Interconnection Study at any time after the Transmission Interconnection Study Agreement is executed by the Customer, the Customer shall be required to reimburse PEF for its expenses, as set forth more fully in the terms and conditions of the Transmission Interconnection Study Agreement. The scope of work shall include, without limitation, the following:
·
Performance of a detailed transmission
planning study of the System to determine transmission additions or modifications
to the System necessitated by the new transmission interconnection, as well as
the configuration and rating of the new transmission interconnection.
·
Performance of a detailed engineering
evaluation in order to make a "good faith" estimate of the cost and
time to complete construction of the new transmission interconnection, and
modifications or additions to the System necessitated by the new transmission
interconnection.
3. Transmission Interconnection and Operating
Agreement
The results of the Transmission Interconnection Study shall provide the basis for the Parties to negotiate a Transmission Interconnection and Operating Agreement. The scope of the Transmission Interconnection and Operating Agreement shall include, without limitation, the following:
·
The responsibility for design, construction
and placing in service the new transmission interconnection, and the
modifications or additions to the System necessitated by the new line
interconnection.
·
The responsibility for payment of costs for
the new transmission interconnection, and modifications or additions to the
System necessitated by the new transmission interconnection.
·
The allocation of ownership, and
responsibility for, operation, control and maintenance of the new transmission
interconnection, and the modifications or additions to the System necessitated
by the new transmission interconnection.
D. Transmission
Interconnection Technical Requirements
The following provides general technical guidelines for interconnecting transmission facilities (i.e. transmission and substation) to the System. PEF shall evaluate each transmission interconnection request on an individual basis to determine the technical requirements particular to that interconnection.
1. Interconnection
Configuration Guidelines
The following are the most probable Customer transmission interconnections to the System along with general requirements:
a.
Radial
Interconnection to the System
For a radial transmission line connected to a single point on the System, the Customer shall comply with the design requirements detailed in III.C.2. Design, ownership, construction, operation, and maintenance shall be defined in the Transmission Interconnection Agreement executed by the Customer prior to construction of facilities, unless existing agreements preclude the requirement for an interconnection agreement. The normal and emergency rating of the transmission facility shall be adequate to meet the intended use. If the radial line will be used to serve Customer end-use load on the Customer’s side of a Delivery Point with the System, the line rating shall have a margin to accommodate forecasted load growth as well as higher than expected peak load.
b.
Interconnection
between Transmission Systems
For a transmission interconnection between the System and another Transmission System, design, ownership, construction, operation and maintenance shall be defined in the Transmission Interconnection Agreement executed by the Customer prior to construction of facilities. Normal and emergency ratings for the interconnection shall be based on results of the Transmission Interconnection Study performed by PEF as set forth herein above. The ratings shall have a margin to accommodate for uncertainty in operating conditions, system load growth, and the future planned interconnected FRCC Transmission System.
c.
Looped
Interconnection to the System
For a
transmission interconnection between two points on the System, PEF shall own,
operate, and maintain this transmission interconnection with a line designed to
satisfy PEF Transmission Design Standards.
Normal and emergency ratings for the transmission interconnection shall
be established based on the results of the Transmission Interconnection Study
performed by PEF as set forth herein above.
The ratings shall have a margin to accommodate for uncertainty in
operating conditions, system load growth, and the future planned System.
2. Transmission
Facility Ratings
The rating
standards for PEF transmission lines and substation equipment are set forth in
“PEF Electrical Facility Ratings” dated
3. Special
Compensation Equipment
The Transmission Interconnection Study may identify special compensation equipment (i.e. capacitors, reactors, special switching, etc.) required to interconnect transmission facilities. Any special requirements for operating the transmission facilities shall be defined in the Transmission Interconnection Agreement executed by the Customer prior to construction of facilities.
The Customer shall be responsible for the real power losses incurred on Customer-owned transmission facilities (lines and transformers) interconnected to the System unless otherwise agreed by the Parties and specifically set forth in the Transmission Interconnection Agreement or other agreements between the Parties.
The Customer shall be responsible for providing reactive compensation for Customer-owned transmission facilities located on the Customer’s side of a Delivery Point connected to the System necessary to meet PEF’s delivery point power factor requirement (see Section IV. B.). The power factor is measured at the point where power exits the System, which is the point of change of ownership between Customer and PEF transmission facilities.
IV. End User Facility Connection
Requirements
The connection of new Network Load to the System, including the negotiation and execution of a required Network Service and Network Operating Agreements between the Parties shall comply with the provisions of the OATT unless other agreements take precedence.
The technical requirements for connecting new Network Load to the System are defined in the Network Service and Network Operating Agreements executed by the Customer pursuant to the provisions of the OATT. Other general guidelines that shall be followed by the Customer shall include, without limitation, the following:
· Load operating characteristics that comply with the Florida Public Service Commission’s standards for power quality.
· The load power factor as specified in the Network Operating Agreement between the Parties, measured at the Point of Delivery.
PROGRESS ENERGY
TABLE OF SPECIFICATIONS
FOR
CUSTOMER’S INTERCONNECTON FACILITIES
Included
in this Specification are the minimum electrical and mechanical design data for
substation, transmission line, and distribution line to be followed for
interconnection with Progress Energy
TABLE 1 - Substation Design Data
TABLE
2 -
Transmission Line Design Data
TABLE
3 -
Distribution Line Design Data
TABLE
4 -
Relay Design Data
Substations shall be designed per the latest editions of the National Electrical Safety Code (ANSI C2),
NEMA Standards, and ANSI standards. The typical acceptable electrical design characteristics are listed
below.
|
Nominal Voltage Rating (kV) |
7.5 |
15 |
25 |
69 |
115 |
230 |
|
BIL (kV) |
95 |
110 |
150 |
350 |
550 |
900 |
|
Typical Fault Duty Design Requirements For Structures and Equipment |
20kA |
20kA |
20kA |
40kA |
40kA |
40kA |
Environmental
Loading
The
general loading requirements for substation structures shall be defined by the
latest edition of ANSI C2 (NESC) approved by the Florida Public Service
Commission's Bureau of Electrical Safety. Substation structures shall be
designed to meet the requirements for transmission line structures, NESC light
loading district with grade B construction and appropriate safety factors. For
extreme wind loading the wind pressure shall be assumed to be 36 psf times the
appropriate shape factors and overload capacity factors.
All grounding and grounding of equipment will be per IEEE 80 latest revision. Customer’s neutral and ground (if applicable) and PEF’s will be bonded at the point of interconnection. The high side connection of generation step-up transformers shall be wye solidly grounded.
TABLE 2
Transmission Line Design Data
Transmission facilities shall be designed per the latest edition of the NESC standards. The minimum acceptable electrical design characteristics are listed below:
|
Nominal Operating Voltage |
69 kV |
115 kV |
230 kV |
|
350 |
550 |
1050 |
|
|
|
|||
|
Conductor Spacing |
|
||
|
Phase to Phase |
7’-0” |
7’-0” |
|
|
Clearance Above Grade |
|||
Mechanical Design Criteria ‑ Environmental Loading
The general loading requirements for a structure shall be defined by the latest edition of ANSI C2 (NESC) approved by the Florida Public Service Commission’s Bureau of Electric Safety.
1
NESC light loading district criteria shall be
used with grade B construction
and appropriate overload capacity factors.
2
For extreme wind
loading, use 135 mph three second gusted wind within 30 miles of the coast and
120 mph three second gusted wind beyond thirty miles from the coast. All
extreme Wind loadings shall incorporate an appropriate Importance Factor
ranging from 1.0 to 1.4 depending on voltage and conductor size. All Extreme
Wind loadings meet or exceed Rule 250C of the 2002 NESC
Customer’s neutral and ground (if applicable) and PEF’s will be bonded at the point of interconnection.
Actual impulse level, conductor spacing, and clearances shall be determined for each respective structure and conductor used during line design activities for the interconnection structures. All phases of the line design activities must conform to all current applicable standards.
TABLE 3
Distribution Line Design Data
Electrical Design Criteria
Distribution facilities shall be designed per the latest edition of the NESC standards. The minimum acceptable electric design characteristics are listed below:
|
15 |
25 |
|
|
95 |
125 |
|
|
350 |
350 |
|
|
|
||
|
Conductor Spacing |
|
|
|
Phase to Phase |
2’-6" |
|
|
5’-0” |
||
|
Clearance above Grade |
||
Mechanical Design Criteria ‑ Environmental Loading
The general loading requirements for a structure shall be defined by the latest edition of ANSI C2 (NESC) approved by the Florida Public Service Commission’s Bureau of Electric Safety.
1 NESC light loading district criteria shall be used with grade B construction and appropriate overload capacity factors.
2 For extreme wind loading, use NESC extreme wind (26 PSF) and PEF hurricane load (36 PSF) criteria with appropriate overload capacity factors.
Grounding
Customer’s neutral and ground (if applicable) and PEF’s ground will be bonded at the point of interconnection.
Note: Where grounding resistors are used, a transformer must isolate the Customer from PEF lines serving other customers.
Fault Current and Voltage
The maximum 3-phase fault current will be limited to approximately 10,000 amps symmetrical including both PEF’s and the Customer’s contributions. Voltage fluctuations will be limited in accordance with PSC/PEF guidelines. The total voltage harmonic distortion must not exceed proposed IEEE 519.
TABLE 4
Transmission lines shall be designed per acceptable industry practices. The following table lists the acceptable protection requirements for transmission lines.
|
|
|
|||
|
Scheme or Requirement |
Below |
|||
|
Directional Comparison |
|
|
|
|
|
|
||||
|
|
||||
|
Pilot Scheme via Fiber Optic |
||||
|
Permissive Over-Reaching Transfer Trip |
|
|
||
|
Pilot Wire via Telephone |
|
|
|
|
|
Bus Differential (For lines Less than 1000 ft.) |
||||
* - 230kV lines require two sets of protective relays
# - The preferred protection at this voltage levels
Control Data
1. The customer shall provide an isolated “N’ dry contact from all interface breakers.
2. The customer shall provide synchronizing capability and no "Dead‑Line" reclosing on all interface breakers.
3. The customer shall provide breaker failure protection on all interface breakers operating at 230kV.
1. The customer shall provide one‑lines showing their system and generator protective equipment.
2. The customer shall provide impedances of the generator and step‑up transformer.
Telemetry Data
1. The customer shall provide space for mounting an RTU whenever the metering point is located at the customer's end of the line.
APPENDIX B
INTERCONNECTION REQUEST FORM
APPENDIX 1 to
Large Generator Interconnection Procedures
(LGIP)
Available at the
http://floasis.siemens-asp.com/
APPENDIX
C
|
PEF
SUBSTATION BUS VOLTAGE SCHEDULES |
|||||
|
Phase |
kV Base |
Per Unit |
Phase- Ground |
PT Ratio |
Meter Indication |
|
540
kV |
500 |
1.080 |
312
kV |
4500/2600-1 |
120
volts |
|
240
kV |
230 |
1.043 |
139
kV |
2000/1155-1 |
120
volts |
|
138
kV |
138 |
1.000 |
80
kV |
1150/664-1 |
120
volts |
|
118
kV |
115 |
1.026 |
68
kV |
1000/577-1 |
118
volts |
|
70.8
kV |
69 |
1.026 |
41
kV |
600/346-1 |
118
volts |
|
23.5
kV |
23 |
1.022 |
13.3
kV |
120-1 |
111
volts |
|
13
kV |
12.5 |
1.040 |
7.5
kV |
60-1 |
125
volts |
|
4.3
kV |
4.16 |
1.034 |
2.5
kV |
20-1 |
125
volts |
NOTE 1: Automatic
voltage controllers are set to maintain a 3 volt bandwidth, i.e., meter volts ±
1 ½ volts.
NOTE 2: Phase
to phase voltage is metered for 69 kV and above.
Lower
voltages are metered phase to ground.
NOTE 3: Voltages
below 69 kV phase-phase are not scheduled by Energy Control and may vary
depending on customer requirements.
NOTE 4: PT ratios are calculated based on meter indication and actual voltage and may not exactly
equal nameplate values.
APPENDIX D
Electrical
Facilities Ratings
Underground
Gas / Oil –
Filled Pipe Cable
Solid
Dielectric Cable
Overhead
Rating
Methodology
Circuit
Ratings
Bus Ampacity Rating
Autotransformers
Normal
Ratings
Emergency
Ratings
Generator Step-up
Transformers
Circuit Breakers
Current
Transformers
Switches
Wave
Traps
Relay
Settings
Series Equipment
Limitations
TRANSMISSION LINES
Underground Transmission Lines
Gas / Oil
– Filled Pipe Cable
The gas- and oil-filled pipe-type cable on the PEF system was installed between 1958 and 1969, and has undergone ampacity rating changes over the years. The reasons for these changes are based on the condition of the equipment as well as the level of risk that can be accepted for each individual circuit. As a result, each underground circuit is studied and evaluated individually for ampacity. No provisions are made for emergency overload ampacity. These cables are monitored regularly for temperature and gas concentrations.
The only circuit using solid dielectric transmission cable on the PEF system was installed in 1994. Its rating was matched to the winter emergency rating of the overhead transmission circuit in series with it. The ampacity and voltage requirements were provided to each cable manufacturer on the bidding list, along with the soil conditions anticipated and the construction method proposed. The cable was engineered to those specifications. The cable manufacturer supplied all necessary compatible accessories. No provisions were made for emergency overload ampacity.
This procedure is cost effective, as it provides the optimum ampacity required. Any other selection means would result in extra ampacity that cannot be utilized, or in inadequate ampacity which would force the cable to become the limiting element in the transmission circuit. It is anticipated that future solid dielectric cables will be sized in this manner.
Overhead Transmission Lines
The ampacity of an overhead transmission line is based on the design criteria used when the circuit was engineered. It is not simply a function of wire size. While wire size may be used to determine a thermal limit for a given set of ambient conditions such as air temperature, wind speed, emissivity, etc., that thermal limit is not always the limiting factor for circuit ampacity. In fact, as operating voltages increase, thermal limits become less of an issue. Other limiting conditions can be conductor sag, series equipment ratings, and stability / power transfer issues.
Design criteria used for transmission lines have evolved over time. The appropriate NESC Edition used for a specific line can usually be found on the plan and profile drawings for that line. Alternatively, one of two charts based on wire size can also be used to determine circuit ampacity. The system one-line diagrams indicate which chart needs to be used for each specific circuit.
Regardless of which ampacity ratings are used, all
transmission lines must satisfy the applicable NESC Edition clearance
requirements. All transmission lines
which commenced construction after
It must be emphasized that ratings exist for specific transmission circuits – not simply one ampacity for a given conductor size.
Different loading limits exist for overhead transmission lines. The wind criteria are defined as follows:
Maximum Continuous Rating (MCR1) – assumes a 1.5 mile per hour wind perpendicular to the conductor. This corresponds to the “normal” rating or “Rate A” for all existing or new lines.
Maximum Continuous Rating (MCR3) – assumes a 3 mile per hour wind perpendicular to the conductor. This corresponds to the “two-hour emergency” rating or “Rate B” for new lines constructed after August 8, 1995, and for existing lines that have been re-rated to this criteria. Note that not all circuits have this rating.
Emergency Maximum Rating (EMR1) – assumes a 1.5 mile per hour wind perpendicular to the conductor. This corresponds to the “two-hour emergency” rating or “Rate B” for existing lines not re-rated to the MCR3 criteria.
Emergency Maximum Rating (EMR3) – assumes a 3 mile per hour wind perpendicular to the conductor. This rating is not used for planning purposes.
In addition, the
following criteria are assumed for all rated transmission lines:
emissivity = 0.5
absorptivity = 0.5
solar position =
ambient temperature = 40º F Winter / 104º F Summer
The table below provides ampacity and MVA ratings for conductors normally used on the Florida Power Corporation system based on the rating methodology described above.
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AMPACITY RATINGS for
TRANSMISSION CONDUCTORS |
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*
RATING CONDITION WIND |
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CONDUCTOR |
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CONDUCTOR
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TYPES |
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TEMPS |
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** MCR1 |
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1.5 MPH |
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@ MCR |
@ EMR |
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MCR3 |
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3.0 MPH |
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ACSR |
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105C |
140C |
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** EMR1 |
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1.5 MPH |
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AAC/AAAC |
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100C |
130C |
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EMR3 |
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3.0 MPH |
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ACAR |
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105C |
130C |
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MCR = Maximum Continuous Rating |
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ALUMOWELD |
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100C |
130C |
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EMR = Emergency Rating |
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HDB Copper |
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70C |
80C |
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**MCR1/EMR1 Calc by 1983 Method |
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Hytherm Copper |
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115C |
135C |
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SUMMER RATING |
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WINTER RATING |
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CONDUCTOR |
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Ambient Temp = 104F(40C) |
Ambient Temp = 40F(4.4C) |
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SIZE & TYPE |
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MVA |
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MVA |
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* Rating Condition |
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AMPS |
69 kV |
115 kV |
230 kV |
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AMPS |
69 kV |
115 kV |
230 kV |
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ACSR |
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1590 Falcon @ MCR1 |
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1700 |
203 |
339 |
677 |
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1980 |
237 |
394 |
789 |
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@ MCR3 |
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1888 |
226 |
376 |
752 |
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2372 |
283 |
472 |
945 |
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@ EMR1 |
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2040 |
244 |
406 |
813 |
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2265 |
271 |
451 |
902 |
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@ EMR3 |
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2296 |
274 |
457 |
915 |
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2669 |
319 |
532 |
1063 |
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1272 Pheasant @ MCR1 |
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1383 |
165 |
275 |
551 |
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1734 |
207 |
345 |
691 |
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@ MCR3 |
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1635 |
195 |
326 |
651 |
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2054 |
245 |
409 |
818 |
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@ EMR1 |
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1705 |
204 |
340 |
679 |
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1972 |
236 |
393 |
786 |
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@ EMR3 |
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1983 |
237 |
395 |
790 |
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2306 |
276 |
459 |
919 |
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954 Cardinal @ MCR1 |
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1235 |
148 |
246 |
492 |
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1440 |
172 |
287 |
574 |
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@ MCR3 |
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1361 |
163 |
271 |
542 |
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1709 |
204 |
340 |
681 |
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@ EMR1 |
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1515 |
181 |
302 |
604 |
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1655 |
198 |
330 |
659 |
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@ EMR3 |
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1645 |
197 |
328 |
655 |
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1914 |
229 |
381 |
762 |
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954 Redbird @ MCR1 |
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1235 |
148 |
246 |
492 |
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1440 |
172 |
287 |
574 |
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@ MCR3 |
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1387 |
166 |
276 |
553 |
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1742 |
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