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ENERGY STORAGE SYSTEM (ESS) PERFORMANCE SPECIFICATION APPLICABLE TO PROPOSALS FOR ENERGY STORAGE RESOURCES
REQUEST FOR PROPOSALS FOR NEW GENERATION, ENERGY STORAGE AND DEMAND RESPONSE RESOURCES (2013 GS&DR RFP)
(PERFORMANCE SPECIFICATION ISSUE DATE: JANUARY 15, 2014; REVISED MARCH 14, 2014)
1. OVERVIEW AND GENERAL REQUIREMENTS
1.1. The Long Island Power Authority (LIPA) has issued a Request for Proposals (RFP) for New
Generation, Energy Storage and Demand Response Resources, dated October 18, 2013 as
amended November 25, 2013 (2013 DS&GR RFP, hereinafter referred to as “RFP”). Pursuant
to the RFP, LIPA seeks to install up to 250 MW of energy storage resources that are intended
to assist black start operations and to also complement new renewable resources being
contemplated for development in the near future.
1.2. The RFP states that additional technical requirements for Energy Storage Systems (ESS) will
be specified in a separate document. This specification defines these technical
requirements, is to be considered an extension of the RFP, and is applicable to all ESS
proposals submitted in response to the RFP. For any conflicts between technical
characteristics specified in the RFP and this specification, the requirements of this
specification shall control.
1.3. The RFP specifies three different blocks of energy resources that it seeks to procure, and each of these blocks may include ESS.
1.3.1. ESS offered as part of Block 1 shall be interconnected to the Buell, Montauk,
Southampton, and/or Deerfield substations. With the exception of ESS connected
to the Montauk substation, interconnections shall be to the 69 kV buses of these
substations. At Montauk, interconnection shall be to the 23 kV substation bus.
1.3.2. ESS offered as part of Block 2 shall be interconnected to the 138 kV bus of the EF
Barrett substation, and the 69 kV bus of the Holtsville substation.
1.3.3. ESS offered as part of Block 3 may be interconnected to the 138 kV buses at the
Ruland Road or Bagatelle substations, to the 69 kV buses at the West Babylon or
Shoreham substations, or to either the 69 kV or 138 kV buses at the Shoreham,
Glenwood, or Sterling substations.
1.4. The intended utilization of the ESS is for transmission capacity relief and renewable
generation leveling. For Block 2 ESS, an additional intended utilization is system balancing
during black‐start operations. Typically, there will be one discharge/charge cycle per day.
Under various circumstances, there can be multiple cycles in a given day, but this is expected
to be a relatively infrequent occurrence. For the purposes of ESS equipment selection and
application, a maximum of 400 – 500 discharge/charge cycles per year can be expected.
1.5. If an ESS installation qualifies as a BES (Bulk Electric System) element according to NERC
protocols, it will be the ESS owner’s responsibility to register as a Generation Owner (GO),
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identify BES elements within the site and comply with the BES as a generator owner
(http://www.nerc.com/pa/stand/Pages/default.aspx).
2. SYSTEM AND ENVIRONMENTAL CONDITIONS AT POINTS OF INTERCONNECTION
2.1. The environmental conditions used for design and performance calculations shall be no less
severe than the values listed in Table 2‐1.
Table 2‐1 Assumed Environmental Conditions
Maximum ambient dry-bulb temperature 105 degree-F Maximum ambient wet-bulb temperature 80 degree-F Minimum ambient air temperature -20 degree-F Maximum daily average ambient air temperature 90 degree-F
Minimum daily average ambient air temperature 10 degree-F
Maximum relative humidity 100 % Minimum relative humidity 10 % Average annual rain fall 45 inch Extreme rain fall 3 in/hr Ice loading conditions ¾ inch Maximum ground snow depth 24 inch Maximum frost depth 3 feet Maximum steady wind velocity (NESC Heavy)
130 mph (165 mph 3 second gusts)
Keraunic level (number of thunderstorm days per year)
30 days/year
Contamination level SALT LADEN Atmosphere within 1000 Feet of ocean and seaways (HEAVY per IEEE C57-19-100, Section 9.1.1 Table 1)
Maximum storm surge height Refer to LIPA’s 2013 GS &DR RFP, Section 2.0(5).G
Seismic Data New York State Building Code Z = 0.18 (The Z numerically corresponds to effective peak acceleration in g on rock/stiff soil S1 conditions - shear wave velocities of about 2,500 ft/sec.
2.2. The ultimate, maximum, minimum, and minimum contingency short‐circuit capacities (three
phase/single phase) of the LIPA system at the specified points of interconnection are
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provided in Appendix A. The ultimate short‐circuit capacity is the value to be used for
substation design short‐circuit withstand calculations and switchgear rating. The maximum
capacity is the short‐circuit level in the present system with all generation on Long Island in
service. The minimum level is the lowest level to be normally encountered, without any lines
or transformers out of service. The minimum contingency level is the most severe line
outage condition for which the ESS is required to remain in unrestricted operation, exclusive
of the system restoration (“black start”) condition.
2.3. The steady‐state (continuous) electrical characteristics of the LIPA transmission system are
specified in Table 2‐2. Any proposed ESS shall operate without restriction over these ranges.
Table 2‐2 LIPA Transmission System Steady‐State Characteristics
System Parameters Values
Continuous ac system voltage range 0.95-1.05 p.u.
Maximum negative-sequence voltage component 2 % of nominal voltage
Maximum zero-sequence voltage component 1 % of nominal voltage
Ambient voltage distortion
(Block 1 ESS interconnection buses)
2nd harmonic 1.0%
3rd harmonic 0.6%
4th harmonic 0.6%
5th harmonic 3.5%
7th harmonic 2.0%
6th, 8th, 9th, 10th 12th harmonic 0.3%
11th, 13th harmonic 0.5%
Harmonics n > 13 0.2%
Total Harmonic Distortion 4.0%
Ambient voltage distortion
(Block 2 and Block 3 ESS interconnection buses)
2nd harmonic 1.0%
3rd harmonic 0.6%
4th harmonic 0.6%
5th harmonic 2.5%
7th harmonic 1.2%
6th, 8th, 9th, 10th 12th harmonic 0.3%
11th, 13th harmonic 0.5%
Harmonics n > 13 0.2%
Total Harmonic Distortion 3.0%
Nominal frequency 60.0 Hz
Normal system frequency range 59.95 – 60.05 Hz
Nominal voltages are 138 kV, 69 kV, or 23 kV rms line-to-line for the interconnection buses as indicated in 1.3.
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2.4. System disturbances can cause the voltage and frequency of the LIPA transmission system
to exceed the steady‐state ranges specified in Table 2‐2. For the temporary operating
conditions specified in Table 2‐3, the ESS shall be designed to withstand these conditions
without damage or loss of availability, and the ESS shall remain functional.
Table 2‐3 LIPA Transmission System Temporary Conditions
System Parameters Values
Temporary voltage range, up to four hour duration (positive sequence component)
0.90 to 1.10 p.u. of nominal voltage
Short-term voltage range (positive sequence component) (See Figure 2-1)
Maximum short-term negative sequence (See Figure 2-2)
Temporary frequency excursions (See Figure 2-3)
Maximum rate of change for frequency – dF/dT 0.25 Hz per second
Figure 2‐1 Short‐term positive sequence voltage range.
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Figure 2‐2 Maximum short‐term negative sequence voltage component.
Figure 2‐3 Maximum temporary frequency deviation.
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2.5. The typical fault clearing times and reclosing delays are specified in Table 2‐4 for the various
LIPA transmission nominal voltage levels. These are to be used for general guidance;
specific clearing times and reclosing delays may differ. LIPA will provide specific clearing
times and reclose delays, at the request of the Respondent, after ESS proposal selection.
Table 2‐4 LIPA Transmission System Typical Fault Clearing and Reclose Delay Times
Nominal Voltage
Primary Clearing
Backup Clearing
Reclose Delay
138 kV 5 Cycles 15 cycles 0.5 ‐ 2.0 Seconds
69 kV 7 cycles 22 cycles 0.5 ‐ 2.0 Seconds
23 kV 7 cycles 22 cycles 0.5 ‐ 2.0 Seconds
2.6. Any ESS proposed for Block 2 shall be capable of operating in a black‐start condition where
the ESS is paralleled with one or more generating units. During such operation, the short‐
circuit capacity may be limited to that provided by the specific generating unit or units
participating in the black‐start operation. For these black start conditions, the minimum
short‐circuit capacity available at the EF Barrett 138 kV bus is 239 A and at the Holtsville 69
kV bus is 478 A. The frequency and voltage during this operating mode is as regulated by
the ESS and generator governor and exciter controls. The ESS shall be functional in this
condition, but certain performance requirements are not applicable to this operating mode,
as specified elsewhere in this document. As a minimum, the ESS shall be designed to be
functional for continuous frequency ranging from 58.0 Hz to 62.0 Hz and continuous voltage
ranging from 0.9 to 1.10 per‐unit of the nominal bus voltage in the black start condition.
2.7. Certain large power electronic conversion based facilities are connected to the LIPA system.
Each of these facilities has controls which pose a potential for interaction with the controls
of the proposed ESS. A summary description of each of these facilities is provided below.
2.7.1. Cross Sound Cable HVDC System
The Cross‐Sound Cable (CSC) 330 MW ‐ voltage‐source converter HVDC system
terminates at the Shoreham 138kV bus. The CSC provides dynamic reactive
compensation similar to a STATCOM. The steady state and dynamic reactive limits
that are applicable to the operation of the Shoreham CSC voltage source converter
station are shown in Figure 2‐4. AC filter components will only be switched during
initial energization and isolation of the CSC. Apart from the energization and isolation
sequence, there will be no filter switching during normal operation over the
complete active power transfer range of the CSC. The maximum MW ramp rate is
estimated at zero to 330 MW in ten (10) minutes.
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Figure 2‐4 Reactive power limits of the CSC Shoreham terminal.
2.7.2. Neptune RTS HVDC System
The 660 MW merchant‐operated Neptune RTS HVDC system is terminated on Long
Island at the Duffy Avenue Converter Station, which is interconnected through a
dedicated 345 kV ac cable and two autotransformers to the LIPA system at the
Newbridge Road 138 kV substation. The Duffy Ave converter station has five
harmonic filter / shunt capacitor banks of approximately 105 MVAR rating per bank.
AC filter dispatch is a function of power transfer, and different allowable filter
combinations are possible. One 115 MVAR shunt reactor is also connected. The Duffy
Avenue converter station also has active harmonic filters. This HVDC system will
normally operate in reactive interchange control mode, but may also operate to
regulate the Newbridge Road 138 kV bus voltage. Overvoltages and undervoltages
caused by disturbances of the HVDC system, including commutation failures and load
rejection, can be expected to affect voltages on the LIPA 138 KV transmission system.
With a minimum system short circuit capacity, the maximum AC voltage change at
the Newbridge Road 138kV bus for switching a single filter capacitor bank is
estimated at 2.0%. The maximum MW ramp rate is estimated as a power transfer level
change of 660 MW in ten minutes.
2.7.3. D‐VAR at East Hampton
A D‐VAR, a type of STATCOM supplied by American Superconductor, is located at the
East Hampton substation. The D‐VAR is interconnected to the 13 kV distribution bus
via four 480V‐13kV pad‐mounted transformers and a breaker. The D‐VAR unit has +/‐
8MVAR capability in continuous mode and a +/‐ 24MVAR capability for up to 2
seconds in contingency mode. This device uses a pulse‐width modulated voltage‐
source converter. The present operating mode of the D‐VAR device is such that it is
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idle during normal voltage conditions and only responds to severe voltage deviations
to regulate the East Hampton 69 kV bus voltage. The device is programmed with an
upper and lower limit defining the nominal 69kV bus voltage band. Currently the
upper limit is 1.05 P.U. and the lower limit is 0.93 P.U. If the 69kV bus voltage goes
outside of this nominal band, the D‐VAR either injects or absorbs VARs to bring the
69kV voltage back within the band. The limits are chosen so as to not require any
output from the D‐VAR during steady‐state conditions. The more severe the voltage
variation from the defined band, the greater is the output of the D‐VAR (up to the full
+/‐ 24MVAR overload capability). The slope setting is 2%. The response time will
depend on a combination of numerous factors such as the actual fault conditions, the
voltage sag, system strength, fault duration etc. The overall system speed of
response is carefully tuned to properly respond to the system disturbance (e.g. fault
conditions, single phase, phase to phase, and three phase) in a manner that is safe
and stable.
2.7.4. Canal Substation DRSS
A Dynamic Reactive Support System (DRSS) supplied by American Superconductor is
in operation connected to the 69kV bus. The DRSS consists of nine D‐VARs (variation
of STATCOM) which are connected to the 69kV bus via five 480V‐13kV transformers
through a 13kV/69 KV 33MVA transformer and a breaker, as well as four 36 MVAR
switched shunt capacitor banks connected to the 69kV bus. The DRSS unit has +180/‐
36 MVAR capability in continuous mode and a +240/‐96 MVAR capability for up to
two seconds in contingency mode. Current operating plans call for the DRSS device
to be only operated in contingency mode to respond to severe system events. The
device is programmed with an upper and lower limit defining the nominal 69kV bus
voltage band. Currently the upper limit is 1.05 P.U. and the lower limit is 0.90 P.U. If
the 69kV bus voltage goes outside of this nominal band, the DRSS either injects or
absorbs VARs to bring the 69kV voltage back within the band. The limits are chosen
so as to not require any output from the DRSS during steady‐state conditions. The
more severe the voltage variation from the defined band, the greater is the output of
the DRSS (up to the full + 240/‐96 MVAR overload capability). The system control
allows the D‐VAR portion of the DRSS to initially respond to changes in system
voltage that bring the Canal 69kV bus voltage outside the nominal band. Capacitors
are then switched as needed as commanded by the control system. The slope setting
is 2%. The response time will depend on a combination of numerous factors such as
the actual fault conditions, the voltage sag, system strength, fault duration etc. The
overall system speed of response is carefully tuned to properly respond to the
system disturbance (e.g. fault conditions, single phase, phase to phase, and three
phase) in a manner that is safe and stable. Response time can be in the order of sub‐
cycle to cycles.
2.7.5. DRSS at Wildwood and Holtsville 138 kV Buses
Dynamic reactive support systems of a design substantially different than the DRSS
at the Canal Substation are presently being commissioned at the Wildwood and
Holtsville 138 kV buses. These devices, provided by Siemens, consist of an “SVC‐Plus”
(STATCOM) and a thyristor‐switched capacitor bank. The SVC‐Plus uses a multi‐
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modular topology. The rating of the SVC‐Plus is +/‐ 75 MVAR, and the rating of the
thyristor‐switched capacitor is 110 MVAR. The total reactive range of the device, as
measured at the 138 kV bus, is +150/‐75 MVAR. The current control strategy is that
this DRSS is normally in a standby mode with the TSC not conducting, and the SVC‐
Plus not injecting any reactive power, unless the 138 kV bus voltage falls outside of a
prescribed range (presently, 0.95 to 1.06 p.u.). If the voltage goes out of this range,
the device will go into a voltage regulation mode and remain in that mode until reset
by a system operator. In voltage control mode, the actual system voltage will not be
controlled exactly to the reference value, but to an adjusted reference, for which the
adjustment or deviation is proportional to the total actual reactive power output of
the system (droop). The SVC Plus control characteristic has an adjustable slope
setting. The slope is presently set at 4.0%.
2.7.6. Brookhaven National Laboratory Synchrotron
Brookhaven National Laboratory has a large synchrotron load that can cyclically
perturb voltage magnitudes on the LIPA transmission system in Eastern Long Island.
These perturbations are characterized as roughly triangular variations in voltage on
the order of 0.002 P.U. magnitude (peak to peak) repeating with a discrete period of
either 1 second or 0.133 seconds, depending on the operating mode of the
synchrotron device at Brookhaven National Laboratory.
3. RATINGS AND CAPABILITIES
3.1. Power Ratings
3.1.1. The discharge power rating of any proposed ESS is the aggregate net power
delivery capacity at the LIPA point(s) of interconnection at one substation, inclusive
of interconnections at all voltage levels within the same substation.
3.1.2. Respondents may choose to offer a temporary overload discharge power rating, on
an optional basis. This short‐term overload capability will be utilized infrequently
for conditions in extremis, and shall be subject to the available stored energy.
Respondents shall define the amount and duration of any overload capability
offered, and any limitations on other performance factors such as reactive power
capability, harmonic performance, etc. that apply to overload operation.
3.2. Energy Ratings
3.2.1. The energy storage capacity shall be such that the ESS can deliver, on a daily basis,
rated power output continuously to the LIPA point of interconnection for twelve
(12) hours.
3.2.2. The ESS shall be capable of delivering an amount of energy equal to the rated
discharge power times twelve (12) hours for power levels less than the rated
discharge power.
3.2.3. ESS proposed for Block 1 applications shall be able recharge from the final state of
charge (SOC) resulting from the discharge cycle specified in 3.2.1, to the initial SOC
that was present before this discharge cycle, within a period of eight (8) hours. The
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maximum power level required to perform this recharge, as measured at the LIPA
point of interconnection, is defined as the charge power rating for the respective
ESS.
3.2.4. ESS proposed for Block 2 and Block 3 applications shall be able recharge from the
final state of charge (SOC) resulting from the discharge cycle specified in 3.2.1, to
the initial SOC that was present before this discharge cycle, within a period of
twelve (12) hours. The maximum power level required to perform this recharge, as
measured at the LIPA point of interconnection, is defined as the charge power
rating for the respective ESS.
3.3. Reactive Power Capacity
With the LIPA point of interconnection bus voltage at the nominal value, the reactive
power capacity shall be as described in Figure 3‐1 and as follows:
3.3.1. When operating at the rated discharge power, each ESS shall have leading and
lagging reactive power capability sufficient to provide a power factor of 0.9 or less
at the LIPA point of transmission interconnection.
3.3.2. At zero real power, and in the energized standby mode, the ESS shall have a
minimum reactive power supply capability, and a minimum reactive power
absorption capability, as measured at the LIPA point of interconnection, that is
equal in MVAR to the rated discharge power capacity in MW.
3.3.3. At absolute values of real recharge power level equal or greater than the discharge
power rating, the capacity to supply and absorb reactive power shall be at least as
great as the amount specified in 3.3.1 for the rated discharge power level.
3.3.4. At power levels having absolute magnitudes greater than zero and less than the
rated discharge power level, the minimum reactive power capability shall be linearly
interpolated between the reactive power requirements for zero power and the
rated discharge power.
3.3.5. Reactive power capability in excess of the specified minima may be proposed and
will be considered in the evaluation.
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Figure 3‐1 Reactive power requirements at nominal voltage
3.4. Voltage and Frequency Conditions
3.4.1. The real power capacity specified by the Respondent, exclusive of any emergency
overload capacity that may be optionally offered, shall be available over the entire
range of steady‐state voltage and frequency conditions at the LIPA point of
interconnection as specified in 2.3.
3.4.2. The reactive power capacity specified in 3.3 shall be available over the entire range
of frequency conditions at the LIPA point of interconnection as specified in 2.3.
3.4.3. At LIPA point of interconnection bus voltage levels other than nominal, but greater
than or equal to 0.95 per unit of nominal and less than 1.05 per unit of nominal, the
reactive power requirements are adjusted as shown in Figures 3‐2 and 3‐3. The
dependent axis in this figure represents the percentage of the reactive power
capacity as specified in 3.3
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Figure 3‐2 Reactive power supplied to LIPA point of interconnection
Figure 3‐2 Reactive power absorbed from LIPA point of interconnection
3.4.4. For voltage levels at the LIPA point of interconnection between 0.5 p.u. and 0.95
p.u., the output current may be limited to the current magnitude required to deliver
rated power to the point of interconnection at 0.9 lagging power factor at 0.95 p.u.
voltage. In this undervoltage regime, priority shall be given to supply of reactive
current over supply of real current.
3.4.5. For positive sequence voltage component levels less than 0.5 p.u. or negative
sequence voltage components greater than 0.2 p.u. at the LIPA point of
interconnection, the ESS may temporarily cease operation (conversion blocked),
but shall remain physically connected and available for immediate restart and
resumption of operation as specified in 6.5.2 upon voltage recovery. Allowable
exceptions to the immediate restart requirement are specified in 6.6.
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4. OPERATING MODES
4.1. Real Power Modes
Each ESS shall be capable of operating in the following real power control modes:
4.1.1. Normal discharge mode – operation with power delivered from the ESS to the grid
point of interconnection up to the rated power. The ESS shall meet all
requirements of normal operation, including the reactive power requirements
specified in 3.3 when operating in this mode, when the voltage and frequency at the
LIPA point of interconnection is within the ranges stated in 2.3.
4.1.2. Emergency discharge mode (optional) is defined as operation with power delivered
from the ESS to the grid point of interconnection greater than the rated value, up
to the emergency overload rating. Reactive power output may be limited while
operating in this mode as necessary to avoid exceeding equipment ratings.
4.1.3. Normal recharge mode, which is defined as operation with power delivered to the
ESS from the grid point of interconnection. The ESS shall meet all requirements of
normal operation, including the reactive power requirements specified in 3.3 when
operating in this mode, when the voltage and frequency at the LIPA point of
interconnection are within the ranges stated in 2.3.
4.1.4. Energized standby mode – In this mode, the ESS is connected to the LIPA point of
interconnection and the real power delivered to or extracted from the point of
interconnection is zero, net of any power required to supply auxiliaries and to
maintain a constant state of charge in the ESS. The ESS shall be capable of the full
reactive power range while in this mode, and shall be available to discharge power
without delay if dispatched, or in response to an underfrequency event as specified
in 5.1.3.
4.1.5. De‐energized standby mode. In this mode, the ESS is physically disconnected from
the LIPA point of interconnection, and the ESS is available to be re‐energized and
deliver up to the power discharge rating within ten (10) minutes of being
dispatched by the system operator.
4.1.6. System restoration mode (Block 2, only). In this mode, the ESS shall be operated in
conjunction with a specified synchronous generator or generators (typically,
combustion turbines) in order to perform black‐start system restoration. The
primary objective of the ESS operation in this mode is to assist the synchronous
generators by regulating the frequency of the isolated island by control of the ESS
real power charge and discharge. The ESS is not required to supply any loads or to
energize any portion of the grid independent of a synchronous generator. This
mode is not required for ESS proposed for Blocks 1 or 3.
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4.2. Reactive Power Modes
The operating modes for control of ESS reactive power are specified below. These reactive
power modes are in addition to, and will exist simultaneously with, the real power modes
specified in 4.1.
4.2.1. Voltage Regulation Mode
The reactive power output of the ESS is controlled to regulate the voltage of the LIPA
point of interconnection bus.
4.2.2. Constant Reactive Power Mode
The reactive power output of the ESS is controlled to yield a constant value of
reactive power to the LIPA point of interconnection.
4.2.3. Voltage Regulation Standby Mode
The ESS maintains a zero steady‐state reactive power output as measured at the LIPA
point of interconnection, until such time as the voltage at the point of
interconnection bus exceeds settable thresholds. When these thresholds are
exceeded, reactive power control reverts to the voltage regulation mode, until reset.
5. CONTROL AND SYSTEM OPERATOR INTERFACE REQUIREMENTS
5.1. Power Regulation
5.1.1. With the exception of operation during the conditions stipulated below, the real
power flow to or from the LIPA point of interconnection shall be regulated to the
ordered value, +/‐ 0.02 per unit on the rated discharge power base. Exception
conditions are:
a) While ramping between power dispatch levels.
b) Voltage and frequency conditions at the LIPA point of interconnection bus
outside of the ranges specified in 2.3.
c) Operation in the system restoration mode.
5.1.2. Changes in power regulation setpoint shall be executed by ramping at a constant
rate. The power ramp rate shall be adjustable locally or through the LIPA Energy
Management System .
5.1.3. If the ESS is operating in any mode other than the offline standby or system
restoration modes, the real power setpoint of the ESS shall be adjusted in
proportion to deviation of the frequency from settable deadband thresholds as
depicted in Figure 5‐1. The proportionality factor, or droop, of this governor
function shall be settable from 0% to 10% frequency variation causing 1.0 p.u. change
in the power set point. The deadband thresholds shall be settable between 0 to 2.0 Hz. The sum of the dispatched power and this governor adjustment may be
limited to the charge power rating during overfrequency and the greater of the
discharge power rating and the emergency discharge power rating (if optionally
offered).
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Figure 5‐1 Governor function
5.1.4. When operating in the system restoration mode (Block 2 ESS only), the discharge
and recharge power of the ESS shall be used to regulate the frequency of the
islanded subsystem. The following frequency control requirements apply to this
mode:
5.1.4.1. ESS real power in the system restoration mode will be controlled by a
regulator having an adjustable frequency reference, and an adjustable droop.
The frequency reference shall be adjustable between 58 and 62 Hz, and the
droop shall be adjustable from zero to 10% . The frequency regulation
(governor) settings for the system restoration mode shall be independent
from the settings for the normal modes specified in 5.1.3. The power control
will have a bias setting, such that the ESS power is controlled to a settable
value when the frequency is equal to the reference frequency value.
5.1.4.2. When in the system restoration mode, the ESS may be exposed to and shall
be required to operate with frequencies and voltages outside of the normal
range specified in 2.3. The ESS shall function with continuous positive‐
sequence components of the LIPA point of interconnection bus voltage
between 0.90 and 1.10 per‐unit of the nominal voltage, and frequency
between 57 and 62 Hz. Voltage imbalance, as defined by the LIPA point of
interconnection bus voltage negative sequence component, can be as large
as 3% of nominal voltage during this mode. Real and reactive power
capability may be limited, as specified in 3.4.4, for voltages less than 0.95 per
unit at the point of interconnection.
5.2. Reactive Power Regulation
5.2.1. Voltage Regulation Mode
In the voltage regulation mode, the positive sequence component of the LIPA point
of interconnection bus voltage shall be regulated to a reference value selected by the
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LIPA system operator. The voltage regulation mode shall be available when
operating in any of the real power modes.
5.2.1.1. The range of settable voltage reference values shall extend at least from
0.95 to 1.05 per‐unit of the nominal voltage of the LIPA point of
interconnection bus.
5.2.1.2. Changes to the voltage reference value shall be executed by continuous
ramping, with the ramp rate settable locally or through the LIPA EMS .
5.2.1.3. The voltage regulation control shall have a droop characteristic (adjustment
of the voltage reference in proportion to the delivered reactive power)
which may be set through the LIPA EMS between the values of 0% and 10%
(percent voltage setpoint adjustment per per‐unit of the rated reactive
power capability based, on the rated discharge power and a power factor 0f
0.9).
5.2.2. Constant Reactive Power Regulation Mode
When operating in the constant reactive power regulation mode, the ESS shall be
controlled to deliver a constant value of net reactive power to the LIPA point of
interconnection. The constant reactive power mode shall be available when in the
normal discharge, recharge, energized standby, or system restoration operating
modes.
5.2.2.1. The reactive power reference shall be settable by the LIPA system operator
between the maximum rated lagging reactive power and maximum rated
leading reactive power, as defined in 3.3, for the real power reference level.
5.2.2.2. Changes to the reactive power reference shall be executed by ramping at a
constant rate. The ramp rate shall be settable locally or through the LIPA
EMS.
5.2.2.3. During real power reference ramping, the control may limit the reactive
power reference to the dispatched value, or the limits defined in 3.3 for the
instantaneous value of the real power reference, whichever requires the
greater power factor.
5.2.3. Voltage Regulation Standby Mode
When operating in the voltage regulation standby mode, the ESS shall maintain zero
steady‐state reactive power output as measured at the LIPA point of
interconnection, whenever the positive‐sequence voltage at the point of
interconnection is greater than or equal to a low‐voltage threshold and less than or
equal to a high‐voltage threshold. If the voltage at the point of interconnection
exceeds the high‐voltage threshold or drops below the low‐voltage threshold for a
duration exceeding 25 ms, the control mode shall revert to the voltage regulation
mode and remain in that mode until reset by local or remote LIPA system operator
intervention. When reset, the ESS shall return to zero reactive power output.
5.2.3.1. The low—voltage threshold shall be continuously settable between 0.8 and
1.0 p.u. of the nominal LIPA point of interconnection bus voltage. The high‐
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voltage threshold shall be continuously adjustable between 1.0 and 1.2 p.u.
The thresholds shall be settable by the LIPA system operator.
5.2.3.2. The voltage regulation reference and droop settings applicable when the
thresholds are exceeded shall be the current settings of the voltage
regulation mode.
5.2.3.3. When reset by a local or LIPA system operator, the reactive power delivered
to the LIPA point of interconnection shall ramp to zero. The applicable ramp
rate is the current voltage reference ramp rate.
5.3. LIPA EMS System Interface
5.3.1. A LIPA Energy Management System interface (SCADA RTU) shall be provided by the
Respondent, and shall be located at each ESS site for use by the LIPA Systems
Operator to dispatch the ESS.
5.3.2. The LIPA EMS interface shall provide the means to input the following control
setpoints and commands for each ESS:
a) Real power dispatch setpoint, which shall include both positive (discharge
power delivered to the LIPA point of interconnection) values and negative
(recharge power taken from the LIPA system) ranges. The extent of the
settable range shall be from the maximum discharge power to the maximum
rated recharge power. If an optional emergency overload discharge
capability is offered and accepted, the settable range shall extend to this
value.
b) Ramp rate in MW per minute, or alternatively, specified as the time over
which the power will be ramped from the previous setpoint to the most
recent setpoint.
c) “Power Ramp Execute” command, which is a signal to commence ramping
from the previous real power dispatch setpoint to the most recent setpoint.
d) “Power Ramp Hold” command, upon which the real power ramp will stop
immediately at its present value and remain at that value until the Ramp Hold
command is released.
e) Selection of the reactive power control mode; inclusive of the voltage
regulation mode, constant reactive power mode, and the standby voltage
regulation mode.
f) Voltage regulation setpoint
g) Voltage regulation droop
h) Reactive power regulation setpoint
i) Voltage/reactive power setpoint ramp time
j) “Voltage/Reactive Ramp Execute” command, which is a signal to commence
ramping from the previous voltage or reactive power setpoint to the most
recent setpoint.
k) “Voltage/Reactive Ramp Hold” command, upon which the voltage or reactive
power setpoint ramp will stop immediately at its present value and remain at
that value until the Ramp Hold command is released.
18
l) Standby voltage regulation mode upper and lower voltage thresholds,
beyond which the voltage regulation mode is activated.
5.3.3. ESS proposed for Block 2 shall have the restoration mode functionality specified in
4.1.6. To facilitate this mode, the LIPA EMS interface for these ESS shall have the
capability of initiating the following additional setpoints and commands:
a) Restoration mode command. When this command is set TRUE, the ESS shall
operate in the restoration mode. The power output shall be used to regulate
frequency and the reactive power used to regulate the LIPA point of
interconnection bus voltage.
b) Frequency regulation setpoint.
c) Frequency regulation droop setting.
d) ESS power level bias.
5.3.4. The LIPA EMS interface shall, as a minimum, include the following real‐time
monitoring information:
a) Present state of charge, calibrated in terms of the net MW‐hours of energy
that can be delivered to the LIPA point of interconnection at the rated
discharge power level.
b) The amount of energy that can be withdrawn from the LIPA system to reach
the maximum state of charge for the storage capacity that is available.
c) Available ESS power capacity in both the discharge and recharge modes.
d) Real and reactive power delivered to the LIPA point of interconnection
e) Voltage of the LIPA point of interconnection
5.3.5. The human interface for the LIPA System Operator will be via the LIPA EMS.
Separate terminals, display units, or consoles for the ESS will not be used.
6. DYNAMIC PERFORMANCE
6.1. Dynamic Control Response
The following dynamic control response shall be provided by each ESS for conditions within
the normal ranges as specified in 2.3 and with the minimum post‐contingency short‐circuit
capacities at the LIPA points of interconnection buses as specified in Appendix A.
6.1.1. Power regulator response times shall be such that for any step change of voltage at
the LIPA point of interconnection within the normal range as defined in 2.3, the
power delivered to the LIPA point of interconnection shall be brought within 0.02
per‐unit of the power regulator setpoint value within 100 ms, without further
excursion outside of this band, using the rated maximum discharge power as the
per‐unit base.
6.1.2. Voltage regulator response shall be such that, for any step change of voltage at the
LIPA point of interconnection within the normal range as defined in 2.3, the change
in ESS reactive power output shall reach 90% of the final steady‐state change in
reactive power within 100 ms, and the reactive power change shall not overshoot
the final reactive power change by more than 10% of the final change. The settling
time for such a step shall be less than 250 ms. The settling time is defined as the
19
time from the initiating step until the reactive power output remains within a band
of 5% of the final steady‐state value relative to the steady‐state reactive power
output change.
6.1.3. Reactive power controller response shall be such that for any step change of
voltage at the LIPA point of interconnection within the normal range as defined in
2.3, the ESS reactive power output delivered to the LIPA point of interconnection
shall be brought within 0.02 per‐unit of the reactive power controller setpoint value
within 100 ms, without further excursion outside of this band, using the rated
maximum discharge power as the per‐unit base.
6.2. System Restoration Mode Control
During the system restoration mode of operation (applicable to ESS in Block 2, only), the
ESS will be paralleled with a synchronous generator in order to supply load to an islanded
portion of the LIPA system. The real power of the ESS shall be controlled to maintain the
frequency of the islanded subsystem, and the reactive power controlled to maintain the
voltage at the LIPA point of interconnection, within tolerable constraints. Dynamic
performance modeling parameters, including exciter and governor data, for the specific
generator to which each ESS will normally be paralleled in a restoration scenario will be
provided by LIPA at the Respondent’s request. In addition, the impedances of branches
between the terminals of this generator and the ESS point of interconnection bus will also
be provided to the Respondent by LIPA. Based on operation in parallel with the specified
generator, or a different generator with equivalent or less constraining characteristics, the
following ESS performance shall be provided:
6.2.1. Frequency regulation response shall be sufficient to maintain the frequency of the
islanded subsystem within a range of 59 to 61 Hz for a step change in real load of
6.0 MW applied to the islanded subsystem, with the subsystem initially at 59.5 Hz.
6.2.2. Voltage regulation response shall be sufficient to maintain the voltage at the LIPA
point of interconnection bus within the range of 0.9 to 1.1 p.u. for a step change in
reactive load of 4.5 MVAR applied to the islanded subsystem, with this bus voltage
initially at 0.95 p.u.
6.3. Control Stability
6.3.1. The performance of each ESS shall be stable and without poorly damped
oscillations in real or reactive power output for any system condition yielding a
short circuit capacity equal or greater than the minimum post‐contingency short‐
circuit capacity listed in 2.2 at the respective LIPA point of interconnection.
6.3.2. The design of each ESS shall avoid excessive hunting (defined as underdamped
control response), repetitive large variations in voltage or power (greater than 1%),
and the creation of under‐ or over‐voltage conditions.
6.3.3. The stability of each ESS shall be independent of the status of any other ESS
provided by Respondent, and independent of any signals communicated from
remote locations.
20
6.3.4. Each ESS shall not engage in or cause adverse or unstable interactions with other
controls, including generator excitation controls, capacitor switching controls, and
transformer tap changer controls, or other power electronic systems including
existing HVDC systems, other dynamic reactive support devices as described in
Section 2, or other ESS.
6.3.5. The ESS control shall self‐monitor for unstable behavior, including that caused by
contingencies resulting in short‐circuit capacities less that those listed in 2.2. Upon
detection of unstable behavior, the ESS controls shall take corrective action.
6.3.6. If control instability occurs with short‐circuit capacity at the LIPA point of
interconnection bus greater than or equal to the minimum post‐contingency short
circuit capacity specified in 2.2, then the affected ESS shall not be returned to
service until the cause is identified and corrected to LIPA’s satisfaction.
6.4. Interaction With Other Power‐Electronic Controlled Transmission Systems
6.4.1. Respondent shall have primary responsibility to investigate and correct any actual
or potential interactions with any other power electronic‐based transmission
system that is in commissioned service or under construction prior to the date of
the commissioning of the proposed ESS
6.4.2. Respondent shall be required to cooperate with LIPA and the party responsible for
any new power electronic‐based transmission system installed or proposed to be
installed after the commissioning of the proposed ESS. This cooperation shall
include providing parameters and control characteristics necessary to investigate
and correct any potential or actual interactions between the systems.
6.5. Performance Continuity
6.5.1. The continuous operation of each ESS shall not be disrupted by minor disturbances.
Disruption of continuous operation shall be defined as deviation from the
dispatched power order greater than the lesser of 0.1 per‐unit power, on the
maximum discharge rating base, and 20% of the dispatched power order, for
duration in excess of 50 ms. A minor disturbance is defined to be:
a) Voltage transients caused by switching of any reactive bank constituting a
component of the ESS design.
b) Energization at any point of the ac voltage waveform of any LIPA system
capacitor banks, transmission lines, or transformers.
c) Dynamic voltage swings of less than 10% magnitude with an oscillatory period of
one second or longer.
6.5.2. Operation of an ESS may temporarily cease for disturbances such as LIPA system
faults resulting in a positive sequence voltage component at the LIPA point of
interconnection less than 0.5 p.u., or a negative‐sequence voltage component in
excess of 0.2 p.u. Unless the severity of the voltage disturbance exceeds the
extreme disturbance criteria listed in 6.6.1, the ESS shall remain physically
connected during the temporary cessation of operation and shall commence
recovery within one cycle of the recovery of the system voltage to a value greater
than 0.6 p.u. in all phases. ESS power transfer shall be restored to dispatched
21
power order within 200 ms if the LIPA point of interconnection bus voltage returns
to 0.95 p.u. or greater. If the LIPA point of interconnection voltage settles to a
lower post‐fault value, then the recovery shall be to the current‐limited power level
as specified in 3.4.4, within 200 ms of fault clearing.
6.5.3. During disturbances more severe than those defined in 6.5.1 as minor disturbances,
but not as severe as those defined in 6.5.2 where temporary suspension of ESS
operation is permitted, each ESS shall remain in operation to deliver power with
limitations as specified in 3.4.4.
6.5.4. Failure of an ESS to recover from a disturbance in accordance with 6.5.2, or failing
to ride through a disturbance as defined in 6.5.1 and 6.5.3, may cause the ESS to be
removed from service at LIPA’s sole discretion, and may be prohibited to return to
service until the cause for the noncompliance is identified and corrected to LIPA’s
satisfaction. The unavailability caused by this removal from service shall be
included in the ESS availability and reliability performance metrics.
6.6. Tripping Criteria
6.6.1. Disturbances of the following severities, or greater, are defined as extreme
conditions:
a) Positive‐sequence component of the fundamental frequency bus voltage at the
LIPA point of interconnection for the specific ESS, greater than the upper limit
or less than the lower limit as specified in Figure 2‐1. For the period up to 0.5
seconds, the upper voltage limit specified in Figure 2‐1 shall be applied to the
greater of the fundamental‐frequency positive‐sequence bus voltage in p.u. on
the nominal line‐to‐line rms voltage, the crest phase‐to‐ground voltage of any bus phase in p.u. of 32 times the nominal line‐to‐line rms voltage, and the
crest phase‐to‐phase voltage of any AC bus phase in p.u. of 2 times the
nominal line‐to‐line rms bus voltage.
b) Negative‐sequence component of the fundamental frequency bus voltage at
either the LIPA point of interconnection bus for each ESS greater than the limits
specified in Figure 2‐2.
c) Frequency, as measured at the LIPA point of interconnection bus, outside of the
limits specified in Figure 2‐3.
d) System conditions causing the short‐circuit capacity at the LIPA point of
interconnection bus to be less than the minimum post‐contingency short‐circuit
capacity listed in 2.2, provided that the system condition is not the result of the
performance of any ESS or generating unit provided by the Respondent to LIPA.
6.6.2. An ESS may trip and lock out, without adverse impact to the ESS availability and
reliability metrics, under the following circumstances:
a) System conditions defined as extreme in 6.6.1.
b) Disconnection of the LIPA bus section to which the ESS is connected from the
LIPA grid, if the disconnection is not the result of incorrect or substandard
performance of the ESS or its protection systems. This is not applicable to
Block 2 ESS operating in the system restoration mode
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6.7. Inadvertent Islanding
Except in the system restoration mode of operations, defined in 4.1.6, the ESS will not
intentionally be isolated from the interconnected LIPA transmission system. Under
extreme and unanticipated circumstances, the ESS could potentially become islanded from
the main LIPA system, with the possibility that the island could include some portion of the
LIPA system including LIPA equipment and LIPA customers. In the event such inadvertent
islanding occurs:
a) The ESS shall not cause transient or temporary overvoltages at any point on the
LIPA system more severe than the overvoltage envelope (upper curve) defined in
Figure 2‐1. The temporary voltage envelope for a given bus is defined as the plot
of voltage versus time, for which the voltage value at any instant of time is the
maximum instantaneous p.u. value of any phase‐to‐ground or phase‐to‐phase
voltage magnitude (absolute value) during the preceding 16.6666 milliseconds. The crest voltage base for per‐unitization of phase‐to‐ground voltages is 2 3
times the nominal line‐to‐line rms voltage, and the base for phase‐to‐phase
voltages is 2 times the nominal line‐to‐line rms bus voltage. Overvoltage
duration is defined as the total cumulative period of time that the TOV envelope
is at or above the given magnitude as a result of a given islanding event.
b) The ESS shall not cause a recovery voltage or transient recovery voltage in excess
of the capabilities of any circuit breaker that establishes the islanding situation by
opening. If it cannot be satisfactorily demonstrated by simulation, testing, or
field results that the recovery voltage produced by opening the circuit breakers
immediately adjacent to the LIPA bus section to which the ESS is connected, are
within the capabilities of those breakers, then the replacement or upgrading
those circuit breakers may be added to the evaluation of the ESS proposal.
6.8. Temporary and Transient Overvoltages
When connected to the integrated LIPA transmission system, the ESS shall not cause
transient or temporary overvoltages at any point on the LIPA system more severe than the
overvoltage envelope defined in Figure 6‐1. The temporary voltage envelope for a given bus
is defined as the plot of voltage versus time, for which the voltage value at any instant of
time is the maximum instantaneous p.u. value of any phase‐to‐ground or phase‐to‐phase
voltage magnitude (absolute value) during the preceding 16.6666 milliseconds. The crest
voltage base for per‐unitization of phase‐to‐ground voltages is 2 3 times the nominal
line‐to‐line rms voltage, and the base for phase‐to‐phase voltages is 2 times the nominal
line‐to‐line rms bus voltage. Overvoltage duration is defined as the total cumulative period
of time that the TOV envelope is at or above the given magnitude as a result of a single
initiating event.
23
Figure 6‐1 Limits to overvoltage caused by ESS.
6.9. Subsynchronous Torsional Interactions
Power‐electronic conversion devices, particularly those that are intended to provide a
constant power characteristic, can potentially cause negative damping of turbo‐generator
torsional oscillations. This interaction is called sub‐synchronous torsional interaction (SSTI),
and has the potential for causing destruction of the turbine generator. The susceptibility to
SSTI is a function of the degree of electrical coupling between the generator and the power
electronic device, which in this case is an ESS. In addition, the susceptibility is proportional
to the rating of the power electronic device relative to the MVA rating of the generator
with which it might interact. Because LIPA plans to procure generation resources to be
located at most or all of the ESS locations, and these generation resources are of small
rating, the potential for SSTI cannot be dismissed. The potential for SSTI during system
restoration operation (Block 2 ESS) is of particular concern.
6.9.1. Each ESS shall be designed such that the torsional oscillation damping, contributed
by the ESS, is positive over the range of 10 Hz to 50 Hz in the synchronous reference
frame for any generator connected to the same substation as the ESS, at any
voltage level. The electrical damping is the real component of the speed to torque
(Te/rotor) transfer function, as measured from behind the subtransient reactance
of the affected generator.
a) For Block 1 ESS installations, this requirement applies to any short‐circuit
level at the LIPA point of interconnection equal or greater than the
minimum post‐contingency short‐circuit capacity listed in2.2.
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b) For Block 2 ESS installations, this requirement applies as well to the system
restoration mode of operation, where the system short‐circuit capacity,
exclusive of the generator paralleled with the ESS, may be zero.
6.9.2. For design, the affected generator shall be assumed to have an MVA rating equal to
the maximum discharge power rating of the ESS, and a subtransient impedance of
0.15 p.u. and a step‐up transformer impedance of 0.10 p.u. on that base. It shall be
assumed that no other generators located at that substation are in operation.
6.9.3. Controls shall be designed to provide positive torsional oscillation damping over the
full real power and reactive power ranges, and in all operating modes, of the ESS.
6.9.4. If positive torsional damping cannot be demonstrated over the entire frequency
range specified in 6.9.1, the ESS Supplier shall alternatively demonstrate that
torsional instability does not occur with the specific generators that LIPA intends to
parallel with the ESS, or any other generators interconnected to the same
substation, for any system condition as specified by 6.9.1
6.10. Required Dynamic Models
6.10.1. Positive‐Sequence Fundamental‐Frequency Model
6.10.1.1. For each ESS, the Respondent shall provide to LIPA a model, implemented in
the Siemens PTI PSS/E dynamic simulation software, Version 32.1.1, that
accurately represents the control characteristics and dynamic behavior of
the ESS in response to balanced voltage and frequency disturbances, to the
extent that such can be validly represented in this type of simulation
platform (up to 5 Hz bandwidth in the synchronous reference frame). This
model shall be provided to LIPA prior to the ESS being placed into
commercial operation.
6.10.1.2. A fully detailed model is required and a general model is not acceptable.
6.10.1.3. The PSS/E model shall be validated for accurate representation of
disturbances that are within the model’s appropriate range of application,
using a validated electromagnetic transients model or full‐scale testing.
6.10.1.4. The PSS/E model shall be fully documented.
6.10.1.5. The PSS/E model must be non‐proprietary and shall be accessible to other
utilities, system operators, asset owners, and other entities associated with
the interconnected transmission network.
6.10.1.6. The PSS/E model shall be updated by the Respondent prior to any change to
the ESS controls or control parameters that materially affects the dynamic
performance.
6.10.1.7. The Respondent shall ensure compatibility of the provided PSS/E model with
the version of PSS/E used by LIPA, as well as compatibility of the latest PSS/E
version released by Siemens PTI. Upgrades and modification of the models
to maintain compatibility with these PSS/E versions shall be the responsibility
of the Respondent.
25
6.10.2. Electromagnetic Transient Model
6.10.2.1. For each ESS, the Respondent shall provide to LIPA an electromagnetic
transients model, implemented in the PSCAD simulation software, Version
4.2 or later, that accurately represents the control characteristics and
dynamic behavior of the ESS in response to balanced and unbalanced
voltage, phase, and frequency disturbances with up to a 1 kHz bandwidth of
simulation validity. This model shall be provided to LIPA prior to the ESS
being placed into commercial operation.
6.10.2.2. The PSCAD model shall use the same power converter control software
algorithms as used in the actual equipment, or a fully validated
approximation of these controls that provides modeling fidelity across the
specified simulation validity bandwidth.
6.10.2.3. An averaged power converter model may be substituted for a full switching
model, provided the averaged model provides valid representation over the
specified bandwidth and represents the interactions across the converter,
between the ac and dc sides.
6.10.2.4. The Respondent must provide documentation establishing the validity of the
model, such as comparisons between model results and full‐scale test results
for a sufficient range of tests.
6.10.2.5. The PSCAD model may be proprietary, and be bound by reasonable non‐
disclosure agreements. The model must be made available to LIPA, LIPA’s
agents and consultants, and any other party as directed by LIPA, provided
that the party is not in direct competition with the Respondent or the
Respondent’s ESS equipment manufacturer.
6.10.2.6. The PSCAD model may be provided in a compiled, “black box” form such
that the details of the model are not disclosed. Information needed to utilize
the model, however, must be adequately documented.
6.10.2.7. Information needed to utilize the model shall be fully documented.
6.10.2.8. The PSCAD model shall be updated by the Respondent prior to any change to
the ESS controls or control parameters that materially affects the transient
or dynamic performance.
6.10.2.9. The Respondent shall ensure compatibility of the provided PSCAD model
with the version of PSCAD specified by LIPA. Upgrades and modification of
the models to maintain compatibility with new PSCAD versions shall be the
responsibility of the Respondent.
7. SHORT‐CIRCUIT CONTRIBUTION
7.1. Respondents shall fully describe the current contributions of the proposed ESS to near and
remote faults. The short‐circuit current contribution characterization shall include:
7.1.1. Three‐phase, single‐phase, phase‐to‐phase, and double‐phase to ground fault types.
26
7.1.2. Characterization of fault current contributions in phase as well as sequence
component formats.
7.1.3. Indication of the phase angle of the current contribution relative to the residual
voltage value at the ESS terminals during the fault.
7.1.4. Description of non‐fundamental‐frequency current components.
7.1.5. Dynamic variations in the ac components of current contribution as well as decay of
the dc component, if any.
7.2. LIPA shall assess whether the short‐circuit contribution of any ESS is responsible for total
fault currents in excess of the rating of any LIPA system circuit breaker or other component.
The costs of upgrading any such equipment subject to excessive duty due to the ESS will be
included in the evaluation of ESS proposals.
8. HARMONICS AND INTERFERENCE
8.1. Harmonic Performance
8.1.1. Harmonic Performance Metrics
Each ESS shall meet the following current and voltage harmonic performance
metrics:
a) Incremental voltage distortion, above the background voltage distortion
level without the ESS in operation, less than:
i. 1%, for any individual frequency.
ii. 3% for the root‐sum‐square of all harmonics (THD).
iii. A TIF factor of 35, defined as follows:
250
2 1
300
n
nn
n CnV
VTIF
where Cn is C‐message weighting factor (Bell System Technical Reference 41009), and n represents the multiple of the fundamental frequency (harmonic order)
b) Current distortion, exclusive of any currents due to background voltage
distortion without the ESS in operation, resulting in an IT product less
than 10,000 A. The IT product is defined as:
250
2
300
n
nnn CnIIT
c) Although the formulae shown for IT and TIF assume that harmonics are
integer multiples of the fundamental frequency, the voltage and current
distortion specifications above are applicable to all frequency
components above 60 Hz and less than or equal to 3 kHz. Interpolation
of the weighting factors shall be used for non‐integer harmonics.
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8.1.2. Harmonic Performance Conditions
The harmonic performance requirements of 8.1.1 shall be met whenever all of the
following conditions exist:
a) all modes of operation, with the exception of the system restoration mode of
operation applicable to Block 2 installations,
b) all levels of real power output between the rated maximum discharge power
and the rated maximum recharge power, inclusive of zero power operation in
the energized standby mode,
c) all levels of reactive power output,
d) system voltage, ambient distortion, and frequency conditions in the normal
ranges, as specified in 2.3, and
e) all system condition resulting in a short‐circuit capacity, exclusive of any
short‐circuit current contribution from the ESS, that is equal or greater than
the minimum short circuit capacity for the LIPA point of interconnection bus,
as listed in2.2.
8.1.3. Harmonic Design Study
For purposes of design, the Respondent shall perform a harmonic performance
study, and provide the results of this report to LIPA prior to ESS commissioning.
8.1.3.1. The Respondent shall define the harmonic source characteristics of their
equipment. This characterization shall define if the device is considered to
be a harmonic voltage or harmonic current source, and will specify the
magnitude of harmonic voltage or current for each operating condition and
power level. This shall be based on analysis, simulation, or full‐scale testing.
If based on analysis or simulation, Respondent shall provide documentation
of validation of the analysis or simulation.
8.1.3.2. If an ESS installation consists of multiple ESS units, Respondent shall
determine the means by which the harmonic voltage or current injections
will be superimposed.
8.1.3.3. The LIPA system impedance at harmonic frequencies, at the point‐of‐
interconnection bus, shall be assumed to be any value within the locus of
points on the R‐X plane defined by the shaded shape as shown in Figure 8‐1.
This locus is the union of points defined by a truncated sector shape, as
shown in Figure 8‐2, and a truncated circle shape, as shown in Figure 8‐3. The
shape parameters for each specific LIPA point of interconnection bus and
harmonic order is specified in Appendix B of this document. Angles in the
inductive quadrant are indicated as positive numbers, and angles in the
capacitive quadrant are indicated as negative numbers.
a) For calculating the individual‐frequency harmonic voltage distortion
performance, the most adverse value within this locus of frequencies
will be used.
b) For calculating multi‐frequency harmonic performance, including
THD, TIF, and IT, the most adverse impedance shall be used for the
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two harmonics with the greatest source magnitude. For the
remaining harmonics, the LIPA system shall be assumed to have zero
impedance if the ESS harmonic source is characterized as a current
source, and as infinite impedance (open circuit) if the ESS harmonic
source is characterized as a voltage source.
c) The harmonic impedance assumptions used for Figure 8‐1 and
Appendix B are intended to be conservative. As an alternative, the
Respondent may opt to calculate more refined harmonic impedance
values. Upon request, LIPA will provide Respondent with PSS/E
loadflow and dynamic databases for the LIPA system and surrounding
interconnected utility systems. With suitable assumptions, to be
approved by LIPA, these data may be converted to a form suitable for
harmonic impedance analysis. The harmonic impedance analysis shall
consider all combinations of the following:
i. Status of LIPA transmission capacitor banks
ii. Status of harmonic filter banks at the Cross Sound Cable and
Neptune RTS HVDC converter stations on Long Island
iii. Single‐contingency outages of lines and transformers on Long
Island
The performance of this alternate calculation of harmonic impedances is
the responsibility of the Respondent. A large number of harmonic
analysis cases are needed to cover these combinations. The results and
utilization of this study shall be subject to LIPA’s review.
Figure 8‐1 Harmonic impedance locus.
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Figure 8‐2 Sector portion of harmonic impedance locus.
Figure 8‐3 Circle portion of harmonic impedance locus. (Anglemin is a negative value in this illustration.)
30
8.1.4. Harmonic Performance Verification
LIPA may perform independent monitoring of the harmonic performance at any time.
Failure to meet these requirements may result in removal of the ESS from service until
the performance issue is resolved to LIPA’s satisfaction.
8.2. Radio Frequency Interference
8.2.1. The Respondent is responsible for any radio frequency interference radiated from
the ESS installation or the connection line between the ESS installation and the LIPA
point of interconnection.
8.2.2. The ESS shall not cause radio frequency noise to be radiated from any LIPA
transmission line or substation that is of greater intensity than 200 uV/m measured
at any point greater than 50’ beyond the perimeter of any substation, or 50’ from
the centerline of any LIPA transmission line. Measurements of radio interference
shall be in accordance with IEEE Standard 430‐1986 (R1991), and made by
instruments compliant with ANSI Standard C63.2‐1996.
9. DEVELOPER ATTACHMENT FACILITIES (DAF)
9.1. DAF Step‐Up Transformer
9.1.1. The winding connection of the DAF Step‐Up transformer shall be such that the ESS
appears as an effectively grounded source as defined by IEEE Standard C62.92.1,
considering the short‐circuit contribution capability and unbalanced fault
performance of the ESS.
9.1.2. Transformer audible noise level shall be compliant with applicable local codes and
ordinances, which typically limit noise to 65 dBA.
9.2. DAF Termination
Termination of the DAF within the LIPA substation shall be in accordance with the latest
LIPA Interconnection Requirements – Transmission Interconnections, as appropriate to the
nature and characteristics of the proposed ESS technology. See
http://www.lipower.org/company/papers/interconnect.html .
9.3. Circuit Breaker
9.3.1. An adequately‐rated circuit breaker shall be installed between the Step‐Up
transformer(s) and the transmission line that terminates in the LIPA substation.
9.3.2. LIPA shall have the ability to remotely trip this circuit breaker.
9.4. Communications Facilities and Interface
9.4.1. For SCADA communication, the LIPA standard is to use a Telvent, Sage 2400 type
RTU. This RTU will communicate with the Hicksville control room (via an ESS
Supplier procured Lease Line).
9.4.2. For any communication between the developers control system to the RTU, DNP
3.0 Serial 9600 N81 protocol shall be used. The data type should be integer not
floating.
31
9.4.3. The Respondent shall provide a SCADA signal list to LIPA.
9.4.4. Respondent will supply the appropriate amount of Digital Input, Digital Output,
Status, Analog out, Analog input cards as needed to the RTU.
9.4.5. The RTU is to be owned and maintained by the Respondent.
9.5. Auxiliary Power
9.5.1. The primary source of auxiliary power for the ESS shall be from the DAF or the
energy stored within the ESS.
9.5.2. The ESS Supplier may procure a backup source of auxiliary power from the LIPA
distribution system.
10. INTERCONNECTION PROTECTION
10.1. Protective Relays
10.1.1. Respondent shall provide all relaying necessary to protect the ESS, its transformer,
and its connection line to the LIPA substation. Respondent shall ensure protection
is properly coordinated with the LIPA interconnection facilities.
10.1.2. The Respondent’s relays may transfer trip LIPA breakers at the interconnection
substation, to the extent needed to provide backup protection. Respondent shall
provide all necessary interfacing equipment. Protection system design shall ensure
that the LIPA breakers are not operated outside of their ratings.
10.1.3. The latest requirements of the LIPA Control and Protection Requirements for
Independent Power Producers – Transmission Interconnection for relaying and
protection, appropriate to the nature and characteristics of the proposed ESS
technology, shall be met. .
See http://www.lipower.org/company/papers/interconnect.html.
10.1.4. The Respondent shall provide reports, including diagrams, to describe the design of
the protection systems, and these designs shall be subject to LIPA’s approval prior
to design finalization.
10.1.5. If the ESS site is not within a LIPA Substation and its grounded and bonded area,
Line Relaying will be required. Wired differential schemes will be considered with
LIPA substations.
10.1.5.1. For a 138 kV connection, a SEL‐311L (87L) and GE‐L90 relays will be required at
the LIPA site and ESS Site.
10.1.5.2. For a 69 kV connection, a SEL‐311L (87L) and SEL‐321 relays will be required at
the LIPA site and ESS Site.
10.1.5.3. For a 33 kV connection, a SEL‐311L and SEL‐321 relays will be required at the
LIPA site and ESS Site.
32
10.2. Recording and Monitoring Devices
10.2.1. A digital fault recorder (DFR) and sequence of events recorder (SER) shall be
installed, and maintained in service, by the ESS Supplier.
10.2.2. As a minimum, the DFR shall record the following:
a) Phase voltages at the interconnection voltage level.
b) Phase currents at the interconnection voltage level.
c) ESS state of charge
d) Real power and reactive power
e) Real power regulator setpoints, as established by any ramping limits
f) Voltage regulator setpoints, as established by any ramping limits
10.2.3. DFR recording triggers shall include, as a minimum:
a) Decrease of any phase voltage below 0.9 p.u.
b) Increase of any phase voltage above 1.10 p.u.
c) Deviation of the instantaneous delivered power from the power regulator
setpoint of more than 0.1 p.u., on the base of the rated discharge power.
d) Breaker status change.
10.2.4. The event inputs for the SER shall be defined by the Respondent and reviewed by
LIPA.
10.2.5. The DFR and SER shall be time stamped with an IRIG satellite clock.
10.2.6. DFR and SER recordings shall be retained by the Respondent for a minimum of 60
days. At any time during this period, LIPA may request the recordings for a
particular event or time period, and the Respondent shall deliver these recordings
within seven (7) days of such request.
11. METERING
The revenue metering requirements for energy storage projects will be consistent with the
latest applicable version of LIPA's Revenue Metering Requirements for Independent Power
Producers. (http://www.lipower.org/company/papers/interconnect.html).
12. LOSSES
12.1. Loss Evaluation Duty Cycles
To facilitate evaluation of losses in proposed ESS, and measurement of losses during
commissioning and periodically thereafter, discharge and recharge power duty cycle
patterns are defined in Appendix C. In each of these duty cycles, the positive percentages
indicate ESS discharge (power delivered to the LIPA point of interconnection) and the
negative percentages indicate ESS recharge (power taken from the LIPA point of
interconnection). All values of power and energy are as measured at the LIPA point of
interconnection. The positive (discharge) percentages are relative to the rated discharge
power of the ESS. The negative percentage levels are relative to the maximum power level
required to achieve a final state of charge equal to the initial state of charge, using the
33
defined power profile. It is emphasized that the percentage bases for the positive and
negative directions are not equal.
As an example to illustrate the definitions of the positive and negative portions of the duty
cycles consider the following two examples:
1) An ESS with a maximum discharge power rating of 12.5 MW, and having round‐
trip losses of 20%, is subjected to Duty Cycle A. The power level base for the
discharge (positive) portion of the cycle is 12.5 MW. Thus, the power delivered to
the LIPA point of interconnection following ramp up shall be 12.5 MW. The
equivalent time period for the discharge period is twelve hours, accounting for
the ramp‐up and ramp‐down times. The delivered energy is 150 MWh. To account
for the losses, the recharge energy is 180 MWh. The equivalent time period of
the recharge portion of the duty cycle is eight hours, accounting for the ramp‐up
and ramp‐down times. Therefore, the power base (100‐% value) for the recharge
(negative) portion of the cycle is 22.5 MW in this example.
2) An ESS with a maximum discharge power rating of 50 MW, and having round‐trip
losses of 10% is subjected to Duty Cycle C. The power level base for the discharge
(positive) portion of the cycle is 50 MW. Thus, the power delivered to the LIPA
point of interconnection following ramp up shall be 25 MW (50% of the 50 MW
base). The equivalent discharge duration is twelve hours, resulting in delivered
energy of 300 MWh. To account for the losses, the recharge energy is 330 MWh.
The equivalent time period of the recharge portion of the duty cycle is twelve
hours. Therefore, the power base (100% value) for the recharge (negative)
portion of the cycle is 27.5 MW in this example.
12.2. Guaranteed Losses
Bidders shall state in their proposal for each ESS the guaranteed maximum net energy for
the duty cycle tests described below. These shall be stated assuming an ambient
temperature of 15C, unity power factor, and the LIPA point of interconnection bus at the
nominal voltage.
12.2.1. Net duty cycle energy (losses) over the full extent of the energy capacity shall be
stated based on Duty Cycle A for Block 1 ESS and Duty Cycle B for Block 2 and Block
3 ESS.
12.2.2. Net duty cycle energy (losses) for the shallow duty cycles defined in Duty Cycles C
and D shall be stated for all ESS. These net energy declarations shall be made for
each of the following state‐of‐charge conditions:
a) Initial state of charge equal to the maximum state of charge. The
maximum state of charge is defined to be the value from which the full
rated energy of the ESS can be delivered to the LIPA point of
interconnection. For example, the shallow duty cycle specified by Duty
Cycle C would cycle the state of charge from 100% to 50% and then back to
100%.
b) State of charge at the end of the discharge phase of the duty cycle test
equal to the minimum state of charge. The minimum state of charge is
34
defined as the state of charge that would exist after the ESS delivers its
rated energy, starting from the maximum state of charge. For example,
the shallow duty cycle specified by Duty Cycle C would cycle the state of
charge from 50% to 0% and then back to 50%.
12.3. Loss Correction Factors
Respondents shall state correction factors or curves for the guaranteed losses defined in
12.2 over the following ranges:
a) Ambient temperature between the minimum and maximum values defined in 2.1.
b) Power factor between 0.9 lagging and 0.9 leading.
c) LIPA point of interconnection bus voltage between 0.95 and 1.05 per‐unit of the
nominal voltage.
12.4. Standby Losses
12.4.1. Respondents shall state the guaranteed maximum average auxiliary power required
to operate in the energized standby mode. These standby losses shall include, but
not be limited to environmental conditioning, control power, interior lighting, and
exterior lighting. Excluded are any losses required to maintain a constant state of
charge in the energy storage medium. The auxiliary losses shall be as a function of
ambient temperature over the range defined in 12.3(a).
12.4.2. Respondents shall state the guaranteed maximum value of power required to
maintain the storage medium at a constant state of charge. These shall be stated
for the state of charge at the maximum, 50% of maximum, and minimum values, and
as a function of temperature over the range defined in 12.3(a).
13. DESIGN STUDIES
13.1. General Requirements
13.1.1. Respondent is responsible for performing the design studies defined in this section.
These studies are intended to show compliance with the performance requirements
of this specification.
13.1.2. All studies should be completed prior to ordering or construction of any equipment
or facilities that may be affected by the results of the studies. Any advanced
equipment ordering or facility construction, prior to completion and approval of
studies, shall be at the sole risk of the Respondent. In no case shall the ESS be
energized or placed into operation prior to the acceptable completion of the
specified studies.
13.1.3. All design studies are subject to LIPA for review and comment. Respondent shall
make reasonable efforts to incorporate or act on these comments.
13.1.3.1. Detailed study scope and study model definitions shall be submitted for LIPA
review prior to commencement of the studies.
35
13.1.3.2. Draft study results shall be submitted to LIPA for review and comment
before finalization.
13.1.3.3. LIPA shall be provided a minimum of fifteen (15) working days to review each
study plan or final study.
13.1.3.4. LIPA shall be given the opportunity to witness any simulator demonstrations
that are relevant to system performance.
13.2. Required Studies
13.2.1. Main Circuit Design Study
In this study, the configuration of the ESS will be defined, along with the ratings of
the major components, including transformers, inverters, storage devices, and
interconnecting lines or cables, such that the rating and performance of the overall
ESS is achieved. Reactive power capacities (leading and lagging) and associated
reactive power characteristics shall be completely defined.
13.2.2. Dynamic Performance Study
Studies shall be performed to verify that the dynamic behavior of the ESS, and its
associated control systems, are in conformance with this specification. The studies
shall be performed using an electromagnetic transient simulation platform, using a
system model that reasonably replicates the actual LIPA system impedance,
damping, and resonant characteristics at the point of interconnection. ESS that are
located in the close vicinity of, or are deemed likely to interact with, the special
power‐electronic systems listed in 2.7 shall have representation of these systems
included in the model. In addition, models for Block 2 ESS shall have adequate models
of the generator to which the ESS will be paralleled during the system restoration
mode of operation. The generator model shall include flux dynamics, exciter and
governor representation. The simulation platform can be a real‐time digital or
analogue simulator using the actual ESS controls, or an off‐line simulation software.
If an off‐line simulation software is used, the models of the ESS shall be detailed and
complete, with documentation of validation against full‐scale real‐time tests
provided. Studies shall consider the range of LIPA system strength between the
minimum post‐contingency short‐circuit capacity to the maximum short‐circuit
capacity as defined in 2.2. Dynamic performance study cases shall include, but are
not limited to:
a) System energization and shutdown
b) Transition between modes of operation
c) Changes in real power, reactive power, and voltage dispatch.
d) Energization of nearby capacitor banks and transformers
e) System faults
f) Internal ESS failures
g) Inadvertent isolation of ESS, including evaluation of recovery voltage
across LIPA breakers and voltages imposed on LIPA equipment.
36
h) Evaluation of potential interaction with other devices
i) Black start scenarios in the system restoration mode (applicable to Block
2 ESS only)
13.2.3. Harmonic Performance Study
A harmonic performance study will be performed to verify that the ESS will conform
to the requirements of 8.1. The execution of the study shall be as specified in 8.1.3. If
any harmonic filters are utilized in the ESS, the study shall consider filter detuning
due to environmental conditions as specified in 2.1, system frequency conditions as
specified in 2.3, and any filter component failures that do not result in the immediate
tripping of the filter or the ESS.
13.2.4. Radio Interference Studies
Respondent will perform studies to verify that the ESS design does not cause radio‐
frequency interference radiated from any LIPA line or substation in excess of the
specifications of 8.2
13.2.5. Subsynchronous Torsional Interaction Study
Respondent will perform a study to verify that the ESS does not contribute negative
torsional damping as specified in 6.9.1. As an alternative, the study may instead verify
that the ESS does not result in torsional instability of any generators as specified in
6.9.4.
13.2.6. Protection Coordination Study
A protection coordination study will be performed by the Respondent to verify that
the design and settings of the protection systems for the ESS and its interconnecting
line and transformer are properly coordinated.
13.2.7. Loss Study
Respondent will provide a detailed calculation of ESS losses to verify and document
that as‐designed losses are less than or equal to the maximum losses stated in the
proposal per Section 12 of this specification.
13.3. Study Data
13.3.1. LIPA shall provide LIPA system data to the Respondent within thirty (30) business
days of Respondent’s data request.
13.3.2. As a minimum, LIPA will provide the Respondent system data in the form of PSS/E
loadflow and dynamic databases, and an Aspen short circuit database.
13.3.3. Detailed parameters and control data for some of the power electronic equipment
listed in 2.7, owned by parties other than LIPA, may not be available. Respondent
shall make a best‐effort assumption of any data which cannot be made available by
LIPA. LIPA will cooperate with the Respondent in making these assumptions and
estimates.
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14. SYSTEM VERIFICATION AND TESTING
14.1. Factory Tests
14.1.1. The control and protection system hardware, with final settings and adjustment,
shall be tested for functional performance in a real‐time simulation environment
where at least the fundamental‐frequency driving point impedance magnitude and
angle of the LIPA point of interconnection is represented. Any adjustments to
control settings subsequent to the factory control system tests shall be reported to
LIPA. LIPA shall have the right to require study results, including simulations or
calculations, to ensure that the control adjustments do not have adverse impact on
performance or equipment duty.
14.1.2. Tests shall be performed to validate the harmonic characteristics of the ESS. LIPA
shall be provided the opportunity to witness the factory tests of the control and
protection system hardware, and the power transformer. LIPA shall be given at
least thirty (30) calendar day notice of the factory test schedule.
14.2. Commissioning Tests
14.2.1. Respondent shall perform commissioning tests to verify the proper installation,
connection, and functional performance of the ESS including all control modes and
protection systems.
14.2.2. Commissioning tests shall be performed to confirm the energy, real power, and
reactive power capabilities of the ESS.
14.2.3. Commissioning tests shall include loss verification, using the duty cycles specified in
12.1.
14.2.4. Compliance with dynamic performance requirements specified in Section 6 shall be
performed during commissioning, to the extent allowable by LIPA system
operations. Dynamic performance testing shall include verification that the
potential for adverse interactions with other controlled devices and power
electronic systems have been adequately mitigated.
14.2.5. Tests to verify compliance with the harmonics and interference requirements of
Section 8 shall be performed during commissioning.
14.2.6. Detailed commissioning test plans and a preliminary test schedule shall be
submitted to LIPA for review and approval sixty (60) calendar days prior to
commencement of any commissioning tests that involve interconnection with the
LIPA system, exclusion of the provision of auxiliary power.
14.2.7. LIPA will be promptly informed by the Respondent of any changes to the
commissioning tests or schedule.
14.2.8. LIPA shall be provided documentation of commissioning test results within thirty
(30) days of the completion of commissioning.
14.2.9. Any on‐line testing will be coordinated through the LIPA System Operator.
38
15. TRAINING
15.1. Respondent will provide training for LIPA System Operators that shall cover:
a) Basic principles of operation
b) Use of the system operator control interface
c) Limitations of operation
d) Contact information
15.2. Because LIPA system operators work on a shift basis, not all operators requiring the
specified training can be available at any one time. Therefore, at least two sessions of the
specified training shall be provided.
16. TECHNICAL PROPOSAL REQUIREMENTS
The following information shall be included in Respondent’s proposal:
16.1. General
16.1.1. Provide a description of each ESS proposed. This description shall include:
a) Proposed location of each ESS facility and the proposed route of any line or
cable required for interconnection to the proposed LIPA point of
interconnection bus.
b) Plot plan and elevation drawings of the ESS facility
c) A single‐line diagram of each ESS facility’s ac configuration, from the power
conversion system, through the facility substation, and the interconnection line
or cable to the LIPA point of interconnection bus.
16.1.2. Submit with the proposal a list of completed energy storage projects and
references.
16.1.3. Define all terms and abbreviations used in the Proposal that are not commonly
accepted industry terminology or abbreviations, and are not defined in the Request
for Proposal.
16.2. Energy Storage Medium
16.2.1. Indicate the manufacturer and model of the energy storage medium (e.g.,
batteries) proposed for each ESS.
16.2.2. List any projects with greater than 10 MWh storage capacity in which this
manufacturer’s equipment has been applied.
16.2.3. Describe any limitations to the operation of the ESS posed by the energy storage
medium.
16.2.4. Describe any environmental control systems, including heating or cooling, required
for the energy storage medium, and describe the susceptibility of these systems to
electrical system disturbances.
39
16.2.5. Describe any degradation of storage capacity expected as a result of age or
utilization. Describe how this degradation will be addressed, such as by planned
replacement, or redundant capacity, in order to maintain the stated net capability.
16.2.6. Describe any environmental hazards presented by the energy storage medium, and
how these hazards will be mitigated in both facility design and operation.
16.3. Interconnection Equipment
16.3.1. Power Conversion Equipment
16.3.1.1. Indicate the manufacturer, model, and ratings of the power conversion
equipment.
16.3.1.2. List all projects of greater than 10 MVA aggregate capacity where this
equipment has been previously applied.
16.3.1.3. Describe the power conversion topology (e.g., two‐level voltage source
converter, multi‐modular voltage source converter, six‐pulse thyristor line‐
commutated converter, etc.).
16.3.1.4. If a voltage‐source converter is used, indicate the effective switching
frequency, and if the switching is synchronous or asynchronous with respect
to the grid voltage.
16.3.1.5. If multiple converters are used, indicate if switching is in any way
coordinated between the converters.
16.3.1.6. Describe any cooling, control power supply, or other auxiliary systems critical
to the power conversion, and describe the susceptibility of these systems to
electrical system disturbances.
16.3.2. Low/Medium Voltage AC System
16.3.2.1. If unit‐level transformers are used to interconnect power converters to a
collection system, describe these transformers in terms of voltage and kVA
rating, winding connection, and leakage impedance.
16.3.2.2. Describe the types and ratings of any switchgear used on the ac system
(collection system) interconnecting the power converters, or unit‐level
transformers, with the main power transformer(s).
16.3.2.3. Describe the protection scheme and any protective relays used in the ac
collection system.
16.3.3. Main Power Transformer(s)
16.3.3.1. Define the characteristics of the main transformers connecting the ESS to
the voltage level of the LIPA point of interconnection, including:
a) Manufacturer
b) MVA rating (OA/FOA, etc.)
c) Voltage ratings
40
d) Winding connection
e) Impedance
f) HV winding BIL
16.3.3.2. Indicate if the main power transformer has any on‐load or off‐load taps. If
so, provide the tap steps and associated winding.
16.3.4. HV Circuit Breaker
16.3.4.1. Indicate the manufacturer, type, and ratings of the circuit breaker between
the ESS main power transformer(s) and the interconnecting line to the LIPA
point of interconnection.
16.3.4.2. Describe how remote tripping of the facility’s HV breaker from the LIPA
substation will be communicated.
16.3.5. Interconnecting Line
16.3.5.1. Indicate the circuit lengths and impedance of the proposed interconnection
lines from the ESS facilities to the points of LIPA interconnection.
16.3.5.2. For cables, indicate the cable type, insulation material, conductor material,
core cross‐sectional area, shield configuration.
16.3.5.3. For overhead lines, indicate the conductor code, framing, and ground wires.
16.4. ESS Ratings
16.4.1. State the rated maximum discharge power capacity of each ESS, as measured at the
LIPA point of interconnection.
16.4.2. State the rated recharge power capacity of each ESS, as measured at the LIPA point
of interconnection.
16.4.3. Indicate if any temporary overload discharge power capacity is offered, as an
option. If offered, state this capacity as well as any limitation on this capacity or on
system performance while providing this capacity.
16.4.4. State the rated energy storage capacity, deliverable to the LIPA point of interconnection, for each ESS.
16.4.5. Indicate the reactive power capacity, at nominal bus voltage, as a function of power
level and LIPA point of interconnection voltage, including both discharge and
recharge operations, as well as the energized standby mode.
16.4.6. Describe limitations to real and reactive power capacity for undervoltage
conditions.
16.5. Controls
16.5.1. Provide a description of the real and reactive power controls, with block diagrams
as appropriate.
16.5.2. For ESS proposed for Block 2, describe the system restoration mode controls.
41
16.5.3. Detail the control inputs, status indications, monitored parameters, and operational
feedback available to the LIPA system operator.
16.6. Dynamic Performance
16.6.1. Describe the approach and simulation tools that will be used to validate compliance
with the specified ESS dynamic performance.
16.6.2. Describe how control stability will be assured over the range of systems strengths
and possible resonant conditions.
16.6.3. Describe the measures to be taken to identify and avoid potential adverse
interactions with other power electronic‐based systems connected to the LIPA
transmission system.
16.6.4. State whether the proposed power conversion equipment has been tested or
certified for ability to ride through voltage or frequency disturbances.
16.6.5. Define the response of the ESS to abrupt isolation from the LIPA grid, without any
prior indications provided to the ESS controls that such isolation will occur. Indicate
the voltages produced and assess the capability of standard circuit breakers to
withstand such an isolation event.
16.6.6. State if any assessments have been made to characterize the interaction of the
proposed power conversion equipment with torsional oscillations of closely‐
coupled turbine generators.
16.6.7. Describe the proposed approach to achieving compliance with 6.8
(Subsynchronous Torsional Interactions). Describe the experience and familiarity of
the Respondent, and the Respondent’s vendors and consultants, with this
phenomenon.
16.6.8. Describe the scope and level of detail to be incorporated into the required PSS/E and PSCAD simulation models to be provided prior to ESS commissioning. Indicate if
the PSCAD model will be considered proprietary, and if so, define the limitations on
utilization and disclosure of this model. Describe the process and tools to be used
to validate the PSS/E and PSCAD models.
16.7. Short Circuit Contribution
16.7.1. Characterize the contribution of the ESS to balanced and unbalanced transmission
faults, both near and remote from the ESS location.
16.7.2. Describe the approach that will be taken to define the detailed short‐circuit
contribution characteristics of the ESS, in both phase and sequence component
formats.
16.8. Harmonic and Radio Interference Performance
16.8.1. Define the harmonic source characteristics of each ESS, in terms of magnitude and
whether characterized as a harmonic current or voltage source. Characterization
shall include non‐integer harmonics (interharmonics) if present.
42
16.8.2. Describe the approach to be taken in the performance of the harmonic
performance study.
16.8.3. State if any harmonic filters will be used in the ESS. If so, define how detuning
conditions will be considered in the harmonic performance analysis.
16.8.4. State if Respondent intends to perform its own study of LIPA system harmonic
impedances to determine driving point harmonic impedances at the LIPA point of
interconnection, or if the default impedance definitions of Appendix B will be used.
If Respondent intends to perform its own harmonic impedance study during the
design phase, describe the approach, extent of model, and analytical tools to be
used to perform this study.
16.8.5. Describe the approach to be taken to verify compliance with radio frequency
interference performance requirements specified in 8.2.
16.9. Protection and Recording Systems
16.9.1. Describe the protection system for the ac portion of the ESS facility, including the
interconnection line, indicating all relaying functions.
16.9.2. Indicate the make and model of all protective relays to be used.
16.9.3. Indicate the make and model of the digital fault recorder at each ESS. Define inputs
to be monitored.
16.9.4. Indicate how sequence of events will be recorded. Indicate all events that will be
monitored.
16.10. Losses
16.10.1. State the guaranteed losses for each loss evaluation duty cycle specified in 12.2.
16.10.2. Provide loss correction factors for ambient temperature, power factor, and LIPA
point of interconnection bus voltage.
16.10.3. State the guaranteed maximum average auxiliary power required to operate in the
energized standby mode.
16.10.4. State the guaranteed maximum power required to maintain a constant state of
charge, with the state of charge at the maximum, minimum, and 50% of maximum
values.
16.10.5. Define any other factors affecting losses.
16.11. Design Studies
16.11.1. Provide a list of all design studies for which results and reports will be provided to
LIPA.
16.11.2. Provide a schedule of all studies, indicating when data from LIPA are required and
when draft reports will be provided.
16.11.3. Describe the approach, model extent (where applicable), data requirements, scope,
and expected results for each study.
43
16.12. Factory Tests
16.12.1. Describe the scope and extent of control and protection system hardware real‐time
tests and performance demonstrations. Indicate the approximate schedule for
these tests.
16.12.2. Describe the scope and extent of the power transformer factory tests. Indicate the
approximate schedule for these tests.
16.12.3. Describe any other factory tests having material importance to the security of the
LIPA transmission system.
16.13. Commissioning Tests
16.13.1. Describe the proposed program for site testing and commissioning, indicating
major tests and expected duration.
16.13.2. Indicate the LIPA support required for performance of the commissioning tests.
16.14. Training.
Describe the proposed operator training program.
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APPENDIX A
LIPA Short Circuit Capacities (kA) (Three‐Phase/Single Phase)
Bus Ultimate Maximum Minimum Min. Contingency
EF Barrett 138 kV 80 / 80 59 / 61 24 / 18 8 / 10
Holtsville 69 kV 63 / 63 37 / 35 13 / 16 8 / 10
Buell 69 kV 43 / 43 11 / 8 4 / 4 0.49 / 0.034
Montauk 23 kV 43 / 43 4 / 3 2 / 1 1 / 0.095
Southampton 69 kV 43 / 43 14 / 16 5 / 4 2 / 2
Deerfield 69 kV 43 / 43 12 / 8 5 / 4 2 / 2
West Babylon 69 kV 43 / 43 28 / 21 16 / 15 10 / 9
Shoreham 69 kV 43 / 43 21 / 19 8 / 10 4 / 3
Shoreham 138 kV 63 / 63 28 / 30 8 / 10 5 / 7
Glenwood 69 kV 63 / 63 40 / 29 23 / 20 10 / 4
Glenwood 138 kV 63 / 63 49 / 44 28 27 2 / 3
Far Rockaway 69 kV 43 / 43 23 / 24 15 / 17 2 / 2
Ruland Road 138 kV 63 / 63 51 / 44 20 / 23 11 / 14
Sterling 69 kV 43 / 43 32 / 16 19 / 12 9 / 5
Sterling 138 kV 63 / 63 30 / 25 15 / 16 3 / 3
Bagatelle 138 kV 63 / 63 26 / 19 14 / 13 7 / 7
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APPENDIX B‐1 ‐ EF BARRETT 138 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.112 6.64 70.0 86.6 0.112 107.0 65.0 86.6
3 0.137 9.96 70.0 87.7 0.137 149.8 -85.0 87.7
4 0.158 13.28 70.0 88.2 0.158 195.4 -85.0 88.2
5 0.177 16.60 70.0 88.5 0.177 243.4 -85.0 88.5
6 0.194 19.92 70.0 88.6 0.194 293.4 -85.0 88.6
7 0.209 23.24 70.0 88.8 0.209 344.8 -85.0 88.8
8 0.223 26.56 70.0 88.9 0.223 397.2 -85.0 88.9
9 0.237 29.88 70.0 88.9 0.237 450.1 -85.0 88.9
10 0.250 33.20 70.0 89.0 0.250 503.1 -85.0 89.0
11 0.262 36.52 70.0 89.0 0.262 555.9 -84.5 89.0
12 0.274 39.84 70.0 89.0 0.274 608.3 -84.0 89.0
13 0.285 43.16 70.0 89.1 0.285 659.9 -83.5 89.1
14 0.296 46.48 70.0 89.1 0.296 710.6 -83.0 89.1
15 0.306 49.80 70.0 89.1 0.306 760.2 -82.5 89.1
16 0.316 53.12 70.0 89.1 0.316 808.6 -82.0 89.1
17 0.326 56.44 70.0 89.1 0.326 855.6 -81.5 89.1
18 0.335 59.76 70.0 89.1 0.335 901.4 -81.0 89.1
19 0.344 63.08 70.0 89.1 0.344 945.6 -80.5 89.1
20 0.353 66.40 70.0 89.1 0.353 988.4 -80.0 89.1
21 0.362 69.72 70.0 89.1 0.362 1029.7 -80.0 89.1
22 0.371 73.03 70.0 89.1 0.371 1069.4 -80.0 89.1
23 0.379 76.35 70.0 89.1 0.379 1107.6 -80.0 89.1
24 0.387 79.67 70.0 89.0 0.387 1144.3 -80.0 89.0
25 0.395 82.99 70.0 89.0 0.395 1179.5 -80.0 89.0
26 0.403 86.31 70.0 89.0 0.403 1213.1 -80.0 89.0
27 0.411 89.63 70.0 89.0 0.411 1245.2 -80.0 89.0
28 0.418 92.95 70.0 89.0 0.418 1275.8 -80.0 89.0
29 0.426 96.27 70.0 89.0 0.426 1304.8 -80.0 89.0
30 0.433 99.59 70.0 89.0 0.433 1332.4 -80.0 89.0
31 0.440 102.91 70.0 89.0 0.440 1358.5 -80.0 89.0
32 0.447 106.23 70.0 88.9 0.447 1383.2 -80.0 88.9
33 0.454 109.55 70.0 88.9 0.454 1406.4 -80.0 88.9
34 0.461 112.87 70.0 88.9 0.461 1428.1 -80.0 88.9
35 0.467 116.19 70.0 88.9 0.467 1448.5 -80.0 88.9
36 0.474 119.51 70.0 88.9 0.474 1467.4 -80.0 88.9
37 0.481 122.83 70.0 88.9 0.481 1484.9 -80.0 88.9
38 0.487 126.15 70.0 88.8 0.487 1501.1 -80.0 88.8
39 0.493 129.47 70.0 88.8 0.493 1515.9 -80.0 88.8
40 0.500 132.79 70.0 88.8 0.500 1529.3 -80.0 88.8
41 0.506 136.11 70.0 88.8 0.506 1541.3 -80.0 88.8
42 0.512 139.43 70.0 88.8 0.512 1552.1 -80.0 88.8
43 0.518 142.75 70.0 88.8 0.518 1561.4 -80.0 88.8
44 0.524 146.07 70.0 88.7 0.524 1569.5 -80.0 88.7
45 0.530 149.39 70.0 88.7 0.530 1576.3 -80.0 88.7
46 0.536 152.71 70.0 88.7 0.536 1581.7 -80.0 88.7
47 0.542 156.03 70.0 88.7 0.542 1585.8 -80.0 88.7
48 0.547 159.35 70.0 88.7 0.547 1588.7 -80.0 88.7
49 0.553 162.67 70.0 88.7 0.553 1590.3 -80.0 88.7
50 0.559 165.99 70.0 88.6 0.559 1590.6 -80.0 88.6
Sector CircleHarmonic
Order
46
APPENDIX B‐2 ‐ HOLTSVILLE GT 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.076 6.13 70.0 86.7 0.076 100.8 65.0 86.7
3 0.093 9.19 70.0 87.6 0.093 133.1 -85.0 87.6
4 0.107 12.26 70.0 88.0 0.107 165.1 -85.0 88.0
5 0.120 15.32 70.0 88.2 0.120 196.7 -85.0 88.2
6 0.131 18.39 70.0 88.4 0.131 227.9 -85.0 88.4
7 0.142 21.45 70.0 88.5 0.142 258.8 -85.0 88.5
8 0.152 24.52 70.0 88.6 0.152 289.3 -85.0 88.6
9 0.161 27.58 70.0 88.6 0.161 319.4 -85.0 88.6
10 0.169 30.64 70.0 88.6 0.169 349.0 -85.0 88.6
11 0.178 33.71 70.0 88.7 0.178 378.3 -84.5 88.7
12 0.186 36.77 70.0 88.7 0.186 407.0 -84.0 88.7
13 0.193 39.84 70.0 88.7 0.193 435.3 -83.5 88.7
14 0.200 42.90 70.0 88.7 0.200 463.1 -83.0 88.7
15 0.208 45.97 70.0 88.7 0.208 490.3 -82.5 88.7
16 0.214 49.03 70.0 88.7 0.214 516.9 -82.0 88.7
17 0.221 52.09 70.0 88.7 0.221 542.9 -81.5 88.7
18 0.227 55.16 70.0 88.7 0.227 568.3 -81.0 88.7
19 0.234 58.22 70.0 88.7 0.234 593.1 -80.5 88.7
20 0.240 61.29 70.0 88.6 0.240 617.3 -80.0 88.6
21 0.246 64.35 70.0 88.6 0.246 640.8 -80.0 88.6
22 0.251 67.42 70.0 88.6 0.251 663.6 -80.0 88.6
23 0.257 70.48 70.0 88.6 0.257 685.8 -80.0 88.6
24 0.262 73.55 70.0 88.6 0.262 707.2 -80.0 88.6
25 0.268 76.61 70.0 88.6 0.268 728.0 -80.0 88.6
26 0.273 79.67 70.0 88.5 0.273 748.0 -80.0 88.5
27 0.278 82.74 70.0 88.5 0.278 767.4 -80.0 88.5
28 0.284 85.80 70.0 88.5 0.284 785.9 -80.0 88.5
29 0.289 88.87 70.0 88.5 0.289 803.8 -80.0 88.5
30 0.293 91.93 70.0 88.5 0.293 820.9 -80.0 88.5
31 0.298 95.00 70.0 88.4 0.298 837.3 -80.0 88.4
32 0.303 98.06 70.0 88.4 0.303 852.9 -80.0 88.4
33 0.308 101.13 70.0 88.4 0.308 867.8 -80.0 88.4
34 0.312 104.19 70.0 88.4 0.312 881.9 -80.0 88.4
35 0.317 107.25 70.0 88.4 0.317 895.2 -80.0 88.4
36 0.321 110.32 70.0 88.3 0.321 907.8 -80.0 88.3
37 0.326 113.38 70.0 88.3 0.326 919.6 -80.0 88.3
38 0.330 116.45 70.0 88.3 0.330 930.6 -80.0 88.3
39 0.335 119.51 70.0 88.3 0.335 940.8 -80.0 88.3
40 0.339 122.58 70.0 88.2 0.339 950.3 -80.0 88.2
41 0.343 125.64 70.0 88.2 0.343 958.9 -80.0 88.2
42 0.347 128.70 70.0 88.2 0.347 966.8 -80.0 88.2
43 0.351 131.77 70.0 88.2 0.351 973.9 -80.0 88.2
44 0.355 134.83 70.0 88.1 0.355 980.2 -80.0 88.1
45 0.359 137.90 70.0 88.1 0.359 985.7 -80.0 88.1
46 0.363 140.96 70.0 88.1 0.363 990.4 -80.0 88.1
47 0.367 144.03 70.0 88.1 0.367 994.3 -80.0 88.1
48 0.371 147.09 70.0 88.0 0.371 997.5 -80.0 88.0
49 0.375 150.16 70.0 88.0 0.375 999.8 -80.0 88.0
50 0.379 153.22 70.0 88.0 0.379 1001.3 -80.0 88.0
Harmonic Order
Sector Circle
47
APPENDIX B‐3 ‐ BUELL 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.465 19.92 70.0 83.7 0.465 171.2 65.0 83.7
3 0.569 29.88 70.0 85.6 0.569 239.2 -85.0 85.6
4 0.657 39.84 70.0 86.5 0.657 311.4 -85.0 86.5
5 0.735 49.80 70.0 87.1 0.735 387.0 -85.0 87.1
6 0.805 59.76 70.0 87.4 0.805 465.2 -85.0 87.4
7 0.870 69.72 70.0 87.7 0.870 545.0 -85.0 87.7
8 0.930 79.67 70.0 87.8 0.930 625.7 -85.0 87.8
9 0.986 89.63 70.0 87.9 0.986 706.6 -85.0 87.9
10 1.039 99.59 70.0 88.0 1.039 787.2 -85.0 88.0
11 1.090 109.55 70.0 88.1 1.090 866.9 -84.5 88.1
12 1.139 119.51 70.0 88.1 1.139 945.3 -84.0 88.1
13 1.185 129.47 70.0 88.2 1.185 1022.2 -83.5 88.2
14 1.230 139.43 70.0 88.2 1.230 1097.2 -83.0 88.2
15 1.273 149.39 70.0 88.2 1.273 1170.2 -82.5 88.2
16 1.315 159.35 70.0 88.2 1.315 1241.0 -82.0 88.2
17 1.355 169.31 70.0 88.2 1.355 1309.5 -81.5 88.2
18 1.395 179.27 70.0 88.2 1.395 1375.7 -81.0 88.2
19 1.433 189.23 70.0 88.2 1.433 1439.6 -80.5 88.2
20 1.470 199.19 70.0 88.2 1.470 1501.0 -80.0 88.2
21 1.506 209.15 70.0 88.2 1.506 1560.0 -80.0 88.2
22 1.542 219.10 70.0 88.1 1.542 1616.7 -80.0 88.1
23 1.576 229.06 70.0 88.1 1.576 1670.9 -80.0 88.1
24 1.610 239.02 70.0 88.1 1.610 1722.8 -80.0 88.1
25 1.643 248.98 70.0 88.1 1.643 1772.3 -80.0 88.1
26 1.676 258.94 70.0 88.1 1.676 1819.6 -80.0 88.1
27 1.708 268.90 70.0 88.0 1.708 1864.5 -80.0 88.0
28 1.739 278.86 70.0 88.0 1.739 1907.2 -80.0 88.0
29 1.770 288.82 70.0 88.0 1.770 1947.7 -80.0 88.0
30 1.800 298.78 70.0 87.9 1.800 1985.9 -80.0 87.9
31 1.830 308.74 70.0 87.9 1.830 2022.0 -80.0 87.9
32 1.859 318.70 70.0 87.9 1.859 2056.0 -80.0 87.9
33 1.888 328.66 70.0 87.8 1.888 2087.9 -80.0 87.8
34 1.917 338.62 70.0 87.8 1.917 2117.6 -80.0 87.8
35 1.945 348.58 70.0 87.8 1.945 2145.3 -80.0 87.8
36 1.972 358.53 70.0 87.7 1.972 2171.0 -80.0 87.7
37 1.999 368.49 70.0 87.7 1.999 2194.7 -80.0 87.7
38 2.026 378.45 70.0 87.7 2.026 2216.3 -80.0 87.7
39 2.053 388.41 70.0 87.6 2.053 2236.0 -80.0 87.6
40 2.079 398.37 70.0 87.6 2.079 2253.8 -80.0 87.6
41 2.105 408.33 70.0 87.6 2.105 2269.6 -80.0 87.6
42 2.130 418.29 70.0 87.5 2.130 2283.5 -80.0 87.5
43 2.155 428.25 70.0 87.5 2.155 2295.5 -80.0 87.5
44 2.180 438.21 70.0 87.4 2.180 2305.6 -80.0 87.4
45 2.205 448.17 70.0 87.4 2.205 2313.8 -80.0 87.4
46 2.229 458.13 70.0 87.4 2.229 2320.2 -80.0 87.4
47 2.253 468.09 70.0 87.3 2.253 2324.7 -80.0 87.3
48 2.277 478.05 70.0 87.3 2.277 2327.4 -80.0 87.3
49 2.301 488.01 70.0 87.2 2.301 2328.3 -80.0 87.2
50 2.324 497.96 70.0 87.2 2.324 2327.3 -80.0 87.2
Harmonic Order
Sector Circle
48
APPENDIX B‐4 – MONTAUK 23 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.632 13.28 70.0 82.5 0.632 96.2 65.0 82.5
3 0.774 19.92 70.0 84.8 0.774 135.5 -85.0 84.8
4 0.894 26.56 70.0 86.0 0.894 177.8 -85.0 86.0
5 1.000 33.20 70.0 86.6 1.000 222.8 -85.0 86.6
6 1.095 39.84 70.0 87.0 1.095 269.8 -85.0 87.0
7 1.183 46.48 70.0 87.3 1.183 318.4 -85.0 87.3
8 1.265 53.12 70.0 87.5 1.265 368.0 -85.0 87.5
9 1.341 59.76 70.0 87.7 1.341 418.2 -85.0 87.7
10 1.414 66.40 70.0 87.8 1.414 468.6 -85.0 87.8
11 1.483 73.03 70.0 87.9 1.483 518.7 -84.5 87.9
12 1.549 79.67 70.0 87.9 1.549 568.4 -84.0 87.9
13 1.612 86.31 70.0 88.0 1.612 617.3 -83.5 88.0
14 1.673 92.95 70.0 88.0 1.673 665.3 -83.0 88.0
15 1.732 99.59 70.0 88.0 1.732 712.1 -82.5 88.0
16 1.789 106.23 70.0 88.0 1.789 757.6 -82.0 88.0
17 1.844 112.87 70.0 88.1 1.844 801.8 -81.5 88.1
18 1.897 119.51 70.0 88.1 1.897 844.6 -81.0 88.1
19 1.949 126.15 70.0 88.0 1.949 885.9 -80.5 88.0
20 2.000 132.79 70.0 88.0 2.000 925.7 -80.0 88.0
21 2.049 139.43 70.0 88.0 2.049 963.9 -80.0 88.0
22 2.097 146.07 70.0 88.0 2.097 1000.6 -80.0 88.0
23 2.144 152.71 70.0 88.0 2.144 1035.8 -80.0 88.0
24 2.190 159.35 70.0 88.0 2.190 1069.4 -80.0 88.0
25 2.236 165.99 70.0 87.9 2.236 1101.6 -80.0 87.9
26 2.280 172.63 70.0 87.9 2.280 1132.2 -80.0 87.9
27 2.323 179.27 70.0 87.9 2.323 1161.3 -80.0 87.9
28 2.366 185.91 70.0 87.9 2.366 1188.9 -80.0 87.9
29 2.408 192.55 70.0 87.8 2.408 1215.1 -80.0 87.8
30 2.449 199.19 70.0 87.8 2.449 1239.9 -80.0 87.8
31 2.490 205.83 70.0 87.8 2.490 1263.3 -80.0 87.8
32 2.529 212.46 70.0 87.7 2.529 1285.2 -80.0 87.7
33 2.569 219.10 70.0 87.7 2.569 1305.8 -80.0 87.7
34 2.607 225.74 70.0 87.7 2.607 1325.0 -80.0 87.7
35 2.645 232.38 70.0 87.6 2.645 1342.9 -80.0 87.6
36 2.683 239.02 70.0 87.6 2.683 1359.5 -80.0 87.6
37 2.720 245.66 70.0 87.6 2.720 1374.8 -80.0 87.6
38 2.756 252.30 70.0 87.5 2.756 1388.7 -80.0 87.5
39 2.792 258.94 70.0 87.5 2.792 1401.4 -80.0 87.5
40 2.828 265.58 70.0 87.4 2.828 1412.9 -80.0 87.4
41 2.863 272.22 70.0 87.4 2.863 1423.1 -80.0 87.4
42 2.898 278.86 70.0 87.4 2.898 1432.0 -80.0 87.4
43 2.932 285.50 70.0 87.3 2.932 1439.8 -80.0 87.3
44 2.966 292.14 70.0 87.3 2.966 1446.3 -80.0 87.3
45 2.999 298.78 70.0 87.2 2.999 1451.6 -80.0 87.2
46 3.033 305.42 70.0 87.2 3.033 1455.8 -80.0 87.2
47 3.065 312.06 70.0 87.2 3.065 1458.7 -80.0 87.2
48 3.098 318.70 70.0 87.1 3.098 1460.5 -80.0 87.1
49 3.130 325.34 70.0 87.1 3.130 1461.1 -80.0 87.1
50 3.162 331.98 70.0 87.0 3.162 1460.6 -80.0 87.0
Harmonic Order
Sector Circle
49
APPENDIX B‐5 – SOUTHAMPTON 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.344 15.93 70.0 83.9 0.344 141.8 65.0 83.9
3 0.422 23.90 70.0 85.8 0.422 200.5 -85.0 85.8
4 0.487 31.87 70.0 86.7 0.487 264.3 -85.0 86.7
5 0.545 39.84 70.0 87.3 0.545 332.3 -85.0 87.3
6 0.597 47.80 70.0 87.6 0.597 404.0 -85.0 87.6
7 0.644 55.77 70.0 87.9 0.644 478.4 -85.0 87.9
8 0.689 63.74 70.0 88.0 0.689 554.9 -85.0 88.0
9 0.731 71.71 70.0 88.2 0.731 632.6 -85.0 88.2
10 0.770 79.67 70.0 88.3 0.770 710.9 -85.0 88.3
11 0.808 87.64 70.0 88.3 0.808 789.3 -84.5 88.3
12 0.844 95.61 70.0 88.4 0.844 867.1 -84.0 88.4
13 0.878 103.58 70.0 88.4 0.878 943.9 -83.5 88.4
14 0.911 111.54 70.0 88.4 0.911 1019.5 -83.0 88.4
15 0.943 119.51 70.0 88.5 0.943 1093.4 -82.5 88.5
16 0.974 127.48 70.0 88.5 0.974 1165.4 -82.0 88.5
17 1.004 135.45 70.0 88.5 1.004 1235.4 -81.5 88.5
18 1.033 143.41 70.0 88.5 1.033 1303.2 -81.0 88.5
19 1.062 151.38 70.0 88.5 1.062 1368.8 -80.5 88.5
20 1.089 159.35 70.0 88.5 1.089 1432.0 -80.0 88.5
21 1.116 167.32 70.0 88.5 1.116 1492.8 -80.0 88.5
22 1.142 175.28 70.0 88.5 1.142 1551.2 -80.0 88.5
23 1.168 183.25 70.0 88.4 1.168 1607.2 -80.0 88.4
24 1.193 191.22 70.0 88.4 1.193 1660.7 -80.0 88.4
25 1.218 199.19 70.0 88.4 1.218 1711.9 -80.0 88.4
26 1.242 207.15 70.0 88.4 1.242 1760.6 -80.0 88.4
27 1.266 215.12 70.0 88.4 1.266 1807.0 -80.0 88.4
28 1.289 223.09 70.0 88.3 1.289 1851.0 -80.0 88.3
29 1.312 231.06 70.0 88.3 1.312 1892.7 -80.0 88.3
30 1.334 239.02 70.0 88.3 1.334 1932.2 -80.0 88.3
31 1.356 246.99 70.0 88.3 1.356 1969.4 -80.0 88.3
32 1.378 254.96 70.0 88.3 1.378 2004.3 -80.0 88.3
33 1.399 262.93 70.0 88.2 1.399 2037.1 -80.0 88.2
34 1.420 270.89 70.0 88.2 1.420 2067.7 -80.0 88.2
35 1.441 278.86 70.0 88.2 1.441 2096.1 -80.0 88.2
36 1.461 286.83 70.0 88.1 1.461 2122.5 -80.0 88.1
37 1.482 294.80 70.0 88.1 1.482 2146.8 -80.0 88.1
38 1.501 302.76 70.0 88.1 1.501 2169.1 -80.0 88.1
39 1.521 310.73 70.0 88.1 1.521 2189.3 -80.0 88.1
40 1.540 318.70 70.0 88.0 1.540 2207.5 -80.0 88.0
41 1.560 326.66 70.0 88.0 1.560 2223.7 -80.0 88.0
42 1.578 334.63 70.0 88.0 1.578 2238.0 -80.0 88.0
43 1.597 342.60 70.0 87.9 1.597 2250.4 -80.0 87.9
44 1.616 350.57 70.0 87.9 1.616 2260.8 -80.0 87.9
45 1.634 358.53 70.0 87.9 1.634 2269.3 -80.0 87.9
46 1.652 366.50 70.0 87.8 1.652 2276.0 -80.0 87.8
47 1.670 374.47 70.0 87.8 1.670 2280.7 -80.0 87.8
48 1.687 382.44 70.0 87.8 1.687 2283.7 -80.0 87.8
49 1.705 390.40 70.0 87.8 1.705 2284.8 -80.0 87.8
50 1.722 398.37 70.0 87.7 1.722 2284.0 -80.0 87.7
Harmonic Order
Sector Circle
50
APPENDIX B‐6 – DEERFIELD 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.440 15.93 70.0 84.1 0.440 147.3 65.0 84.1
3 0.539 23.90 70.0 85.9 0.539 206.8 -85.0 85.9
4 0.622 31.87 70.0 86.8 0.622 270.7 -85.0 86.8
5 0.695 39.84 70.0 87.3 0.695 338.1 -85.0 87.3
6 0.762 47.80 70.0 87.7 0.762 408.3 -85.0 87.7
7 0.823 55.77 70.0 87.9 0.823 480.5 -85.0 87.9
8 0.880 63.74 70.0 88.0 0.880 554.0 -85.0 88.0
9 0.933 71.71 70.0 88.2 0.933 628.1 -85.0 88.2
10 0.984 79.67 70.0 88.2 0.984 702.2 -85.0 88.2
11 1.032 87.64 70.0 88.3 1.032 775.9 -84.5 88.3
12 1.077 95.61 70.0 88.3 1.077 848.6 -84.0 88.3
13 1.121 103.58 70.0 88.4 1.121 920.1 -83.5 88.4
14 1.164 111.54 70.0 88.4 1.164 990.1 -83.0 88.4
15 1.205 119.51 70.0 88.4 1.205 1058.3 -82.5 88.4
16 1.244 127.48 70.0 88.4 1.244 1124.7 -82.0 88.4
17 1.282 135.45 70.0 88.4 1.282 1189.0 -81.5 88.4
18 1.320 143.41 70.0 88.4 1.320 1251.1 -81.0 88.4
19 1.356 151.38 70.0 88.4 1.356 1311.1 -80.5 88.4
20 1.391 159.35 70.0 88.4 1.391 1368.9 -80.0 88.4
21 1.425 167.32 70.0 88.4 1.425 1424.5 -80.0 88.4
22 1.459 175.28 70.0 88.4 1.459 1477.8 -80.0 88.4
23 1.492 183.25 70.0 88.4 1.492 1528.9 -80.0 88.4
24 1.524 191.22 70.0 88.3 1.524 1577.7 -80.0 88.3
25 1.555 199.19 70.0 88.3 1.555 1624.3 -80.0 88.3
26 1.586 207.15 70.0 88.3 1.586 1668.8 -80.0 88.3
27 1.616 215.12 70.0 88.3 1.616 1711.1 -80.0 88.3
28 1.646 223.09 70.0 88.3 1.646 1751.3 -80.0 88.3
29 1.675 231.06 70.0 88.2 1.675 1789.4 -80.0 88.2
30 1.704 239.02 70.0 88.2 1.704 1825.4 -80.0 88.2
31 1.732 246.99 70.0 88.2 1.732 1859.3 -80.0 88.2
32 1.759 254.96 70.0 88.1 1.759 1891.3 -80.0 88.1
33 1.787 262.93 70.0 88.1 1.787 1921.2 -80.0 88.1
34 1.814 270.89 70.0 88.1 1.814 1949.2 -80.0 88.1
35 1.840 278.86 70.0 88.1 1.840 1975.2 -80.0 88.1
36 1.866 286.83 70.0 88.0 1.866 1999.4 -80.0 88.0
37 1.892 294.80 70.0 88.0 1.892 2021.6 -80.0 88.0
38 1.917 302.76 70.0 88.0 1.917 2041.9 -80.0 88.0
39 1.942 310.73 70.0 87.9 1.942 2060.4 -80.0 87.9
40 1.967 318.70 70.0 87.9 1.967 2077.1 -80.0 87.9
41 1.992 326.66 70.0 87.9 1.992 2092.0 -80.0 87.9
42 2.016 334.63 70.0 87.8 2.016 2105.0 -80.0 87.8
43 2.040 342.60 70.0 87.8 2.040 2116.3 -80.0 87.8
44 2.063 350.57 70.0 87.8 2.063 2125.8 -80.0 87.8
45 2.086 358.53 70.0 87.7 2.086 2133.6 -80.0 87.7
46 2.109 366.50 70.0 87.7 2.109 2139.6 -80.0 87.7
47 2.132 374.47 70.0 87.7 2.132 2143.9 -80.0 87.7
48 2.155 382.44 70.0 87.6 2.155 2146.5 -80.0 87.6
49 2.177 390.40 70.0 87.6 2.177 2147.4 -80.0 87.6
50 2.199 398.37 70.0 87.6 2.199 2146.6 -80.0 87.6
Harmonic Order
Sector Circle
51
APPENDIX B‐7 – WEST BABYLON 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.191 4.98 70.0 85.5 0.191 60.4 65.0 85.5
3 0.234 7.47 70.0 86.8 0.234 83.4 -85.0 86.8
4 0.270 9.96 70.0 87.5 0.270 107.3 -85.0 87.5
5 0.301 12.45 70.0 87.9 0.301 132.0 -85.0 87.9
6 0.330 14.94 70.0 88.1 0.330 157.0 -85.0 88.1
7 0.357 17.43 70.0 88.3 0.357 182.2 -85.0 88.3
8 0.381 19.92 70.0 88.4 0.381 207.4 -85.0 88.4
9 0.404 22.41 70.0 88.4 0.404 232.3 -85.0 88.4
10 0.426 24.90 70.0 88.5 0.426 256.9 -85.0 88.5
11 0.447 27.39 70.0 88.5 0.447 281.0 -84.5 88.5
12 0.467 29.88 70.0 88.6 0.467 304.6 -84.0 88.6
13 0.486 32.37 70.0 88.6 0.486 327.6 -83.5 88.6
14 0.504 34.86 70.0 88.6 0.504 349.9 -83.0 88.6
15 0.522 37.35 70.0 88.6 0.522 371.6 -82.5 88.6
16 0.539 39.84 70.0 88.6 0.539 392.5 -82.0 88.6
17 0.556 42.33 70.0 88.6 0.556 412.7 -81.5 88.6
18 0.572 44.82 70.0 88.6 0.572 432.2 -81.0 88.6
19 0.588 47.31 70.0 88.6 0.588 451.0 -80.5 88.6
20 0.603 49.80 70.0 88.5 0.603 469.0 -80.0 88.5
21 0.618 52.29 70.0 88.5 0.618 486.3 -80.0 88.5
22 0.632 54.78 70.0 88.5 0.632 503.0 -80.0 88.5
23 0.647 57.27 70.0 88.5 0.647 518.9 -80.0 88.5
24 0.660 59.76 70.0 88.5 0.660 534.1 -80.0 88.5
25 0.674 62.25 70.0 88.4 0.674 548.6 -80.0 88.4
26 0.687 64.74 70.0 88.4 0.687 562.5 -80.0 88.4
27 0.701 67.23 70.0 88.4 0.701 575.7 -80.0 88.4
28 0.713 69.72 70.0 88.4 0.713 588.3 -80.0 88.4
29 0.726 72.20 70.0 88.3 0.726 600.2 -80.0 88.3
30 0.738 74.69 70.0 88.3 0.738 611.4 -80.0 88.3
31 0.751 77.18 70.0 88.3 0.751 622.1 -80.0 88.3
32 0.763 79.67 70.0 88.3 0.763 632.1 -80.0 88.3
33 0.774 82.16 70.0 88.2 0.774 641.4 -80.0 88.2
34 0.786 84.65 70.0 88.2 0.786 650.2 -80.0 88.2
35 0.798 87.14 70.0 88.2 0.798 658.4 -80.0 88.2
36 0.809 89.63 70.0 88.2 0.809 666.0 -80.0 88.2
37 0.820 92.12 70.0 88.1 0.820 673.0 -80.0 88.1
38 0.831 94.61 70.0 88.1 0.831 679.3 -80.0 88.1
39 0.842 97.10 70.0 88.1 0.842 685.2 -80.0 88.1
40 0.853 99.59 70.0 88.0 0.853 690.4 -80.0 88.0
41 0.863 102.08 70.0 88.0 0.863 695.1 -80.0 88.0
42 0.874 104.57 70.0 88.0 0.874 699.1 -80.0 88.0
43 0.884 107.06 70.0 87.9 0.884 702.7 -80.0 87.9
44 0.894 109.55 70.0 87.9 0.894 705.6 -80.0 87.9
45 0.904 112.04 70.0 87.9 0.904 708.0 -80.0 87.9
46 0.914 114.53 70.0 87.8 0.914 709.9 -80.0 87.8
47 0.924 117.02 70.0 87.8 0.924 711.2 -80.0 87.8
48 0.934 119.51 70.0 87.8 0.934 711.9 -80.0 87.8
49 0.944 122.00 70.0 87.7 0.944 712.1 -80.0 87.7
50 0.953 124.49 70.0 87.7 0.953 711.8 -80.0 87.7
Harmonic Order
Sector Circle
52
APPENDIX B‐8 –SHOREHAM 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.136 9.96 70.0 86.8 0.136 167.0 65.0 86.8
3 0.166 14.94 70.0 87.6 0.166 216.3 -85.0 87.6
4 0.192 19.92 70.0 87.9 0.192 262.8 -85.0 87.9
5 0.214 24.90 70.0 88.2 0.214 307.0 -85.0 88.2
6 0.235 29.88 70.0 88.3 0.235 349.2 -85.0 88.3
7 0.254 34.86 70.0 88.4 0.254 389.6 -85.0 88.4
8 0.271 39.84 70.0 88.4 0.271 428.4 -85.0 88.4
9 0.288 44.82 70.0 88.4 0.288 465.7 -85.0 88.4
10 0.303 49.80 70.0 88.5 0.303 501.7 -85.0 88.5
11 0.318 54.78 70.0 88.5 0.318 536.4 -84.5 88.5
12 0.332 59.76 70.0 88.5 0.332 569.9 -84.0 88.5
13 0.346 64.74 70.0 88.5 0.346 602.4 -83.5 88.5
14 0.359 69.72 70.0 88.4 0.359 633.7 -83.0 88.4
15 0.371 74.69 70.0 88.4 0.371 664.1 -82.5 88.4
16 0.384 79.67 70.0 88.4 0.384 693.5 -82.0 88.4
17 0.395 84.65 70.0 88.4 0.395 721.8 -81.5 88.4
18 0.407 89.63 70.0 88.4 0.407 749.3 -81.0 88.4
19 0.418 94.61 70.0 88.3 0.418 775.8 -80.5 88.3
20 0.429 99.59 70.0 88.3 0.429 801.4 -80.0 88.3
21 0.439 104.57 70.0 88.3 0.439 826.1 -80.0 88.3
22 0.450 109.55 70.0 88.2 0.450 849.9 -80.0 88.2
23 0.460 114.53 70.0 88.2 0.460 872.8 -80.0 88.2
24 0.470 119.51 70.0 88.2 0.470 894.8 -80.0 88.2
25 0.479 124.49 70.0 88.1 0.479 915.9 -80.0 88.1
26 0.489 129.47 70.0 88.1 0.489 936.1 -80.0 88.1
27 0.498 134.45 70.0 88.1 0.498 955.5 -80.0 88.1
28 0.507 139.43 70.0 88.0 0.507 974.0 -80.0 88.0
29 0.516 144.41 70.0 88.0 0.516 991.7 -80.0 88.0
30 0.525 149.39 70.0 88.0 0.525 1008.5 -80.0 88.0
31 0.534 154.37 70.0 87.9 0.534 1024.4 -80.0 87.9
32 0.542 159.35 70.0 87.9 0.542 1039.4 -80.0 87.9
33 0.551 164.33 70.0 87.9 0.551 1053.6 -80.0 87.9
34 0.559 169.31 70.0 87.8 0.559 1066.9 -80.0 87.8
35 0.567 174.29 70.0 87.8 0.567 1079.4 -80.0 87.8
36 0.575 179.27 70.0 87.7 0.575 1091.0 -80.0 87.7
37 0.583 184.25 70.0 87.7 0.583 1101.7 -80.0 87.7
38 0.591 189.23 70.0 87.7 0.591 1111.6 -80.0 87.7
39 0.599 194.21 70.0 87.6 0.599 1120.6 -80.0 87.6
40 0.607 199.19 70.0 87.6 0.607 1128.8 -80.0 87.6
41 0.614 204.17 70.0 87.6 0.614 1136.1 -80.0 87.6
42 0.621 209.15 70.0 87.5 0.621 1142.5 -80.0 87.5
43 0.629 214.12 70.0 87.5 0.629 1148.1 -80.0 87.5
44 0.636 219.10 70.0 87.4 0.636 1152.8 -80.0 87.4
45 0.643 224.08 70.0 87.4 0.643 1156.7 -80.0 87.4
46 0.650 229.06 70.0 87.4 0.650 1159.7 -80.0 87.4
47 0.657 234.04 70.0 87.3 0.657 1161.8 -80.0 87.3
48 0.664 239.02 70.0 87.3 0.664 1163.1 -80.0 87.3
49 0.671 244.00 70.0 87.2 0.671 1163.5 -80.0 87.2
50 0.678 248.98 70.0 87.2 0.678 1163.1 -80.0 87.2
Harmonic Order
Sector Circle
53
APPENDIX B‐9 –SHOREHAM 138 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.155 19.92 70.0 87.3 0.155 396.6 65.0 87.3
3 0.190 29.88 70.0 88.0 0.190 517.0 -85.0 88.0
4 0.219 39.84 70.0 88.3 0.219 633.0 -85.0 88.3
5 0.245 49.80 70.0 88.5 0.245 745.2 -85.0 88.5
6 0.268 59.76 70.0 88.6 0.268 854.1 -85.0 88.6
7 0.290 69.72 70.0 88.7 0.290 959.9 -85.0 88.7
8 0.310 79.67 70.0 88.7 0.310 1063.1 -85.0 88.7
9 0.328 89.63 70.0 88.8 0.328 1163.7 -85.0 88.8
10 0.346 99.59 70.0 88.8 0.346 1261.8 -85.0 88.8
11 0.363 109.55 70.0 88.8 0.363 1357.5 -84.5 88.8
12 0.379 119.51 70.0 88.8 0.379 1450.9 -84.0 88.8
13 0.395 129.47 70.0 88.8 0.395 1542.0 -83.5 88.8
14 0.409 139.43 70.0 88.8 0.409 1630.8 -83.0 88.8
15 0.424 149.39 70.0 88.8 0.424 1717.3 -82.5 88.8
16 0.438 159.35 70.0 88.8 0.438 1801.6 -82.0 88.8
17 0.451 169.31 70.0 88.8 0.451 1883.6 -81.5 88.8
18 0.464 179.27 70.0 88.7 0.464 1963.2 -81.0 88.7
19 0.477 189.23 70.0 88.7 0.477 2040.6 -80.5 88.7
20 0.489 199.19 70.0 88.7 0.489 2115.7 -80.0 88.7
21 0.501 209.15 70.0 88.7 0.501 2188.5 -80.0 88.7
22 0.513 219.10 70.0 88.7 0.513 2258.9 -80.0 88.7
23 0.525 229.06 70.0 88.7 0.525 2327.0 -80.0 88.7
24 0.536 239.02 70.0 88.6 0.536 2392.8 -80.0 88.6
25 0.547 248.98 70.0 88.6 0.547 2456.2 -80.0 88.6
26 0.558 258.94 70.0 88.6 0.558 2517.2 -80.0 88.6
27 0.569 268.90 70.0 88.6 0.569 2575.8 -80.0 88.6
28 0.579 278.86 70.0 88.5 0.579 2632.0 -80.0 88.5
29 0.589 288.82 70.0 88.5 0.589 2685.9 -80.0 88.5
30 0.599 298.78 70.0 88.5 0.599 2737.3 -80.0 88.5
31 0.609 308.74 70.0 88.5 0.609 2786.3 -80.0 88.5
32 0.619 318.70 70.0 88.5 0.619 2832.9 -80.0 88.5
33 0.629 328.66 70.0 88.4 0.629 2877.0 -80.0 88.4
34 0.638 338.62 70.0 88.4 0.638 2918.7 -80.0 88.4
35 0.647 348.58 70.0 88.4 0.647 2958.0 -80.0 88.4
36 0.657 358.53 70.0 88.4 0.657 2994.8 -80.0 88.4
37 0.666 368.49 70.0 88.3 0.666 3029.1 -80.0 88.3
38 0.675 378.45 70.0 88.3 0.675 3061.0 -80.0 88.3
39 0.683 388.41 70.0 88.3 0.683 3090.4 -80.0 88.3
40 0.692 398.37 70.0 88.3 0.692 3117.3 -80.0 88.3
41 0.701 408.33 70.0 88.2 0.701 3141.8 -80.0 88.2
42 0.709 418.29 70.0 88.2 0.709 3163.8 -80.0 88.2
43 0.718 428.25 70.0 88.2 0.718 3183.3 -80.0 88.2
44 0.726 438.21 70.0 88.2 0.726 3200.3 -80.0 88.2
45 0.734 448.17 70.0 88.1 0.734 3214.8 -80.0 88.1
46 0.742 458.13 70.0 88.1 0.742 3226.9 -80.0 88.1
47 0.750 468.09 70.0 88.1 0.750 3236.4 -80.0 88.1
48 0.758 478.05 70.0 88.0 0.758 3243.4 -80.0 88.0
49 0.766 488.01 70.0 88.0 0.766 3248.0 -80.0 88.0
50 0.774 497.96 70.0 88.0 0.774 3250.0 -80.0 88.0
Harmonic Order
Sector Circle
54
APPENDIX B‐10 –GLENWOOD 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.092 3.46 70.0 86.8 0.092 59.2 65.0 86.8
3 0.113 5.20 70.0 87.6 0.113 75.9 -85.0 87.6
4 0.130 6.93 70.0 87.9 0.130 91.6 -85.0 87.9
5 0.145 8.66 70.0 88.1 0.145 106.2 -85.0 88.1
6 0.159 10.39 70.0 88.3 0.159 120.1 -85.0 88.3
7 0.172 12.12 70.0 88.3 0.172 133.2 -85.0 88.3
8 0.184 13.86 70.0 88.4 0.184 145.7 -85.0 88.4
9 0.195 15.59 70.0 88.4 0.195 157.7 -85.0 88.4
10 0.206 17.32 70.0 88.4 0.206 169.2 -85.0 88.4
11 0.216 19.05 70.0 88.4 0.216 180.3 -84.5 88.4
12 0.225 20.78 70.0 88.4 0.225 190.9 -84.0 88.4
13 0.235 22.52 70.0 88.4 0.235 201.2 -83.5 88.4
14 0.243 24.25 70.0 88.4 0.243 211.1 -83.0 88.4
15 0.252 25.98 70.0 88.3 0.252 220.7 -82.5 88.3
16 0.260 27.71 70.0 88.3 0.260 229.9 -82.0 88.3
17 0.268 29.44 70.0 88.3 0.268 238.8 -81.5 88.3
18 0.276 31.18 70.0 88.3 0.276 247.5 -81.0 88.3
19 0.284 32.91 70.0 88.2 0.284 255.8 -80.5 88.2
20 0.291 34.64 70.0 88.2 0.291 263.8 -80.0 88.2
21 0.298 36.37 70.0 88.2 0.298 271.5 -80.0 88.2
22 0.305 38.11 70.0 88.1 0.305 279.0 -80.0 88.1
23 0.312 39.84 70.0 88.1 0.312 286.1 -80.0 88.1
24 0.319 41.57 70.0 88.1 0.319 293.0 -80.0 88.1
25 0.325 43.30 70.0 88.0 0.325 299.6 -80.0 88.0
26 0.332 45.03 70.0 88.0 0.332 305.9 -80.0 88.0
27 0.338 46.77 70.0 87.9 0.338 312.0 -80.0 87.9
28 0.344 48.50 70.0 87.9 0.344 317.7 -80.0 87.9
29 0.350 50.23 70.0 87.9 0.350 323.2 -80.0 87.9
30 0.356 51.96 70.0 87.8 0.356 328.4 -80.0 87.8
31 0.362 53.69 70.0 87.8 0.362 333.4 -80.0 87.8
32 0.368 55.43 70.0 87.7 0.368 338.0 -80.0 87.7
33 0.374 57.16 70.0 87.7 0.374 342.4 -80.0 87.7
34 0.379 58.89 70.0 87.7 0.379 346.5 -80.0 87.7
35 0.385 60.62 70.0 87.6 0.385 350.4 -80.0 87.6
36 0.390 62.35 70.0 87.6 0.390 353.9 -80.0 87.6
37 0.396 64.09 70.0 87.5 0.396 357.2 -80.0 87.5
38 0.401 65.82 70.0 87.5 0.401 360.3 -80.0 87.5
39 0.406 67.55 70.0 87.5 0.406 363.0 -80.0 87.5
40 0.411 69.28 70.0 87.4 0.411 365.5 -80.0 87.4
41 0.417 71.01 70.0 87.4 0.417 367.7 -80.0 87.4
42 0.422 72.75 70.0 87.3 0.422 369.6 -80.0 87.3
43 0.427 74.48 70.0 87.3 0.427 371.3 -80.0 87.3
44 0.432 76.21 70.0 87.2 0.432 372.7 -80.0 87.2
45 0.436 77.94 70.0 87.2 0.436 373.8 -80.0 87.2
46 0.441 79.67 70.0 87.2 0.441 374.6 -80.0 87.2
47 0.446 81.41 70.0 87.1 0.446 375.2 -80.0 87.1
48 0.451 83.14 70.0 87.1 0.451 375.5 -80.0 87.1
49 0.455 84.87 70.0 87.0 0.455 375.5 -80.0 87.0
50 0.460 86.60 70.0 87.0 0.460 375.3 -80.0 87.0
Harmonic Order
Sector Circle
55
APPENDIX B‐11 –GLENWOOD 138 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.101 5.69 70.0 87.8 0.101 143.5 65.0 87.8
3 0.123 8.54 70.0 88.3 0.123 174.2 -85.0 88.3
4 0.142 11.38 70.0 88.5 0.142 201.1 -85.0 88.5
5 0.159 14.23 70.0 88.6 0.159 225.5 -85.0 88.6
6 0.174 17.07 70.0 88.6 0.174 248.0 -85.0 88.6
7 0.188 19.92 70.0 88.6 0.188 269.2 -85.0 88.6
8 0.201 22.76 70.0 88.7 0.201 289.3 -85.0 88.7
9 0.214 25.61 70.0 88.7 0.214 308.7 -85.0 88.7
10 0.225 28.46 70.0 88.6 0.225 327.3 -85.0 88.6
11 0.236 31.30 70.0 88.6 0.236 345.3 -84.5 88.6
12 0.247 34.15 70.0 88.6 0.247 362.8 -84.0 88.6
13 0.257 36.99 70.0 88.6 0.257 379.7 -83.5 88.6
14 0.266 39.84 70.0 88.6 0.266 396.2 -83.0 88.6
15 0.276 42.68 70.0 88.5 0.276 412.3 -82.5 88.5
16 0.285 45.53 70.0 88.5 0.285 427.9 -82.0 88.5
17 0.294 48.37 70.0 88.5 0.294 443.0 -81.5 88.5
18 0.302 51.22 70.0 88.5 0.302 457.7 -81.0 88.5
19 0.310 54.06 70.0 88.4 0.310 472.0 -80.5 88.4
20 0.319 56.91 70.0 88.4 0.319 485.9 -80.0 88.4
21 0.326 59.76 70.0 88.4 0.326 499.3 -80.0 88.4
22 0.334 62.60 70.0 88.3 0.334 512.3 -80.0 88.3
23 0.342 65.45 70.0 88.3 0.342 524.8 -80.0 88.3
24 0.349 68.29 70.0 88.3 0.349 536.9 -80.0 88.3
25 0.356 71.14 70.0 88.2 0.356 548.6 -80.0 88.2
26 0.363 73.98 70.0 88.2 0.363 559.8 -80.0 88.2
27 0.370 76.83 70.0 88.2 0.370 570.6 -80.0 88.2
28 0.377 79.67 70.0 88.1 0.377 580.9 -80.0 88.1
29 0.384 82.52 70.0 88.1 0.384 590.7 -80.0 88.1
30 0.390 85.37 70.0 88.0 0.390 600.1 -80.0 88.0
31 0.397 88.21 70.0 88.0 0.397 609.0 -80.0 88.0
32 0.403 91.06 70.0 88.0 0.403 617.4 -80.0 88.0
33 0.409 93.90 70.0 87.9 0.409 625.4 -80.0 87.9
34 0.415 96.75 70.0 87.9 0.415 632.9 -80.0 87.9
35 0.421 99.59 70.0 87.9 0.421 639.9 -80.0 87.9
36 0.427 102.44 70.0 87.8 0.427 646.5 -80.0 87.8
37 0.433 105.28 70.0 87.8 0.433 652.6 -80.0 87.8
38 0.439 108.13 70.0 87.8 0.439 658.2 -80.0 87.8
39 0.445 110.97 70.0 87.7 0.445 663.3 -80.0 87.7
40 0.450 113.82 70.0 87.7 0.450 667.9 -80.0 87.7
41 0.456 116.67 70.0 87.6 0.456 672.0 -80.0 87.6
42 0.462 119.51 70.0 87.6 0.462 675.7 -80.0 87.6
43 0.467 122.36 70.0 87.6 0.467 678.9 -80.0 87.6
44 0.472 125.20 70.0 87.5 0.472 681.5 -80.0 87.5
45 0.478 128.05 70.0 87.5 0.478 683.7 -80.0 87.5
46 0.483 130.89 70.0 87.4 0.483 685.4 -80.0 87.4
47 0.488 133.74 70.0 87.4 0.488 686.6 -80.0 87.4
48 0.493 136.58 70.0 87.4 0.493 687.3 -80.0 87.4
49 0.499 139.43 70.0 87.3 0.499 687.5 -80.0 87.3
50 0.504 142.28 70.0 87.3 0.504 687.2 -80.0 87.3
Harmonic Order
Sector Circle
56
APPENDIX B‐12 –FAR ROCKAWAY 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.287 5.31 70.0 84.8 0.287 55.7 65.0 84.8
3 0.351 7.97 70.0 86.3 0.351 76.0 -85.0 86.3
4 0.406 10.62 70.0 87.0 0.406 96.8 -85.0 87.0
5 0.454 13.28 70.0 87.4 0.454 117.9 -85.0 87.4
6 0.497 15.93 70.0 87.7 0.497 139.2 -85.0 87.7
7 0.537 18.59 70.0 87.9 0.537 160.5 -85.0 87.9
8 0.574 21.25 70.0 88.0 0.574 181.7 -85.0 88.0
9 0.609 23.90 70.0 88.1 0.609 202.6 -85.0 88.1
10 0.641 26.56 70.0 88.2 0.641 223.2 -85.0 88.2
11 0.673 29.21 70.0 88.2 0.673 243.5 -84.5 88.2
12 0.703 31.87 70.0 88.2 0.703 263.3 -84.0 88.2
13 0.731 34.53 70.0 88.2 0.731 282.6 -83.5 88.2
14 0.759 37.18 70.0 88.2 0.759 301.4 -83.0 88.2
15 0.786 39.84 70.0 88.2 0.786 319.7 -82.5 88.2
16 0.811 42.49 70.0 88.2 0.811 337.4 -82.0 88.2
17 0.836 45.15 70.0 88.2 0.836 354.6 -81.5 88.2
18 0.861 47.80 70.0 88.2 0.861 371.2 -81.0 88.2
19 0.884 50.46 70.0 88.2 0.884 387.3 -80.5 88.2
20 0.907 53.12 70.0 88.2 0.907 402.8 -80.0 88.2
21 0.930 55.77 70.0 88.2 0.930 417.8 -80.0 88.2
22 0.951 58.43 70.0 88.2 0.951 432.2 -80.0 88.2
23 0.973 61.08 70.0 88.1 0.973 446.1 -80.0 88.1
24 0.994 63.74 70.0 88.1 0.994 459.4 -80.0 88.1
25 1.014 66.40 70.0 88.1 1.014 472.1 -80.0 88.1
26 1.034 69.05 70.0 88.0 1.034 484.3 -80.0 88.0
27 1.054 71.71 70.0 88.0 1.054 496.0 -80.0 88.0
28 1.073 74.36 70.0 88.0 1.073 507.1 -80.0 88.0
29 1.092 77.02 70.0 88.0 1.092 517.7 -80.0 88.0
30 1.111 79.67 70.0 87.9 1.111 527.7 -80.0 87.9
31 1.129 82.33 70.0 87.9 1.129 537.3 -80.0 87.9
32 1.148 84.99 70.0 87.9 1.148 546.3 -80.0 87.9
33 1.165 87.64 70.0 87.8 1.165 554.8 -80.0 87.8
34 1.183 90.30 70.0 87.8 1.183 562.8 -80.0 87.8
35 1.200 92.95 70.0 87.8 1.200 570.2 -80.0 87.8
36 1.217 95.61 70.0 87.7 1.217 577.2 -80.0 87.7
37 1.234 98.27 70.0 87.7 1.234 583.6 -80.0 87.7
38 1.251 100.92 70.0 87.7 1.251 589.6 -80.0 87.7
39 1.267 103.58 70.0 87.6 1.267 595.0 -80.0 87.6
40 1.283 106.23 70.0 87.6 1.283 599.9 -80.0 87.6
41 1.299 108.89 70.0 87.5 1.299 604.4 -80.0 87.5
42 1.315 111.54 70.0 87.5 1.315 608.3 -80.0 87.5
43 1.330 114.20 70.0 87.5 1.330 611.8 -80.0 87.5
44 1.346 116.86 70.0 87.4 1.346 614.7 -80.0 87.4
45 1.361 119.51 70.0 87.4 1.361 617.2 -80.0 87.4
46 1.376 122.17 70.0 87.4 1.376 619.2 -80.0 87.4
47 1.391 124.82 70.0 87.3 1.391 620.6 -80.0 87.3
48 1.405 127.48 70.0 87.3 1.405 621.6 -80.0 87.3
49 1.420 130.13 70.0 87.2 1.420 622.2 -80.0 87.2
50 1.434 132.79 70.0 87.2 1.434 622.2 -80.0 87.2
Harmonic Order
Sector Circle
57
APPENDIX B‐13 –RULAND ROAD 138 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.155 19.92 70.0 87.3 0.155 396.6 65.0 87.3
3 0.190 29.88 70.0 88.0 0.190 517.0 -85.0 88.0
4 0.219 39.84 70.0 88.3 0.219 633.0 -85.0 88.3
5 0.245 49.80 70.0 88.5 0.245 745.2 -85.0 88.5
6 0.268 59.76 70.0 88.6 0.268 854.1 -85.0 88.6
7 0.290 69.72 70.0 88.7 0.290 959.9 -85.0 88.7
8 0.310 79.67 70.0 88.7 0.310 1063.1 -85.0 88.7
9 0.328 89.63 70.0 88.8 0.328 1163.7 -85.0 88.8
10 0.346 99.59 70.0 88.8 0.346 1261.8 -85.0 88.8
11 0.363 109.55 70.0 88.8 0.363 1357.5 -84.5 88.8
12 0.379 119.51 70.0 88.8 0.379 1450.9 -84.0 88.8
13 0.395 129.47 70.0 88.8 0.395 1542.0 -83.5 88.8
14 0.409 139.43 70.0 88.8 0.409 1630.8 -83.0 88.8
15 0.424 149.39 70.0 88.8 0.424 1717.3 -82.5 88.8
16 0.438 159.35 70.0 88.8 0.438 1801.6 -82.0 88.8
17 0.451 169.31 70.0 88.8 0.451 1883.6 -81.5 88.8
18 0.464 179.27 70.0 88.7 0.464 1963.2 -81.0 88.7
19 0.477 189.23 70.0 88.7 0.477 2040.6 -80.5 88.7
20 0.489 199.19 70.0 88.7 0.489 2115.7 -80.0 88.7
21 0.501 209.15 70.0 88.7 0.501 2188.5 -80.0 88.7
22 0.513 219.10 70.0 88.7 0.513 2258.9 -80.0 88.7
23 0.525 229.06 70.0 88.7 0.525 2327.0 -80.0 88.7
24 0.536 239.02 70.0 88.6 0.536 2392.8 -80.0 88.6
25 0.547 248.98 70.0 88.6 0.547 2456.2 -80.0 88.6
26 0.558 258.94 70.0 88.6 0.558 2517.2 -80.0 88.6
27 0.569 268.90 70.0 88.6 0.569 2575.8 -80.0 88.6
28 0.579 278.86 70.0 88.5 0.579 2632.0 -80.0 88.5
29 0.589 288.82 70.0 88.5 0.589 2685.9 -80.0 88.5
30 0.599 298.78 70.0 88.5 0.599 2737.3 -80.0 88.5
31 0.609 308.74 70.0 88.5 0.609 2786.3 -80.0 88.5
32 0.619 318.70 70.0 88.5 0.619 2832.9 -80.0 88.5
33 0.629 328.66 70.0 88.4 0.629 2877.0 -80.0 88.4
34 0.638 338.62 70.0 88.4 0.638 2918.7 -80.0 88.4
35 0.647 348.58 70.0 88.4 0.647 2958.0 -80.0 88.4
36 0.657 358.53 70.0 88.4 0.657 2994.8 -80.0 88.4
37 0.666 368.49 70.0 88.3 0.666 3029.1 -80.0 88.3
38 0.675 378.45 70.0 88.3 0.675 3061.0 -80.0 88.3
39 0.683 388.41 70.0 88.3 0.683 3090.4 -80.0 88.3
40 0.692 398.37 70.0 88.3 0.692 3117.3 -80.0 88.3
41 0.701 408.33 70.0 88.2 0.701 3141.8 -80.0 88.2
42 0.709 418.29 70.0 88.2 0.709 3163.8 -80.0 88.2
43 0.718 428.25 70.0 88.2 0.718 3183.3 -80.0 88.2
44 0.726 438.21 70.0 88.2 0.726 3200.3 -80.0 88.2
45 0.734 448.17 70.0 88.1 0.734 3214.8 -80.0 88.1
46 0.742 458.13 70.0 88.1 0.742 3226.9 -80.0 88.1
47 0.750 468.09 70.0 88.1 0.750 3236.4 -80.0 88.1
48 0.758 478.05 70.0 88.0 0.758 3243.4 -80.0 88.0
49 0.766 488.01 70.0 88.0 0.766 3248.0 -80.0 88.0
50 0.774 497.96 70.0 88.0 0.774 3250.0 -80.0 88.0
Harmonic Order
Sector Circle
58
APPENDIX B‐14 –STERLING 69 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.148 4.19 70.0 86.0 0.148 57.0 65.0 86.0
3 0.181 6.29 70.0 87.1 0.181 75.7 -85.0 87.1
4 0.209 8.39 70.0 87.6 0.209 94.1 -85.0 87.6
5 0.234 10.48 70.0 87.9 0.234 112.0 -85.0 87.9
6 0.256 12.58 70.0 88.1 0.256 129.4 -85.0 88.1
7 0.277 14.68 70.0 88.2 0.277 146.3 -85.0 88.2
8 0.296 16.77 70.0 88.2 0.296 162.8 -85.0 88.2
9 0.314 18.87 70.0 88.3 0.314 178.7 -85.0 88.3
10 0.331 20.97 70.0 88.3 0.331 194.0 -85.0 88.3
11 0.347 23.06 70.0 88.3 0.347 208.9 -84.5 88.3
12 0.362 25.16 70.0 88.3 0.362 223.3 -84.0 88.3
13 0.377 27.26 70.0 88.3 0.377 237.2 -83.5 88.3
14 0.392 29.35 70.0 88.3 0.392 250.6 -83.0 88.3
15 0.405 31.45 70.0 88.3 0.405 263.6 -82.5 88.3
16 0.419 33.55 70.0 88.3 0.419 276.1 -82.0 88.3
17 0.431 35.64 70.0 88.3 0.431 288.1 -81.5 88.3
18 0.444 37.74 70.0 88.3 0.444 299.8 -81.0 88.3
19 0.456 39.84 70.0 88.2 0.456 311.0 -80.5 88.2
20 0.468 41.93 70.0 88.2 0.468 321.8 -80.0 88.2
21 0.480 44.03 70.0 88.2 0.480 332.1 -80.0 88.2
22 0.491 46.13 70.0 88.2 0.491 342.1 -80.0 88.2
23 0.502 48.22 70.0 88.1 0.502 351.7 -80.0 88.1
24 0.513 50.32 70.0 88.1 0.513 360.9 -80.0 88.1
25 0.523 52.42 70.0 88.1 0.523 369.7 -80.0 88.1
26 0.534 54.51 70.0 88.0 0.534 378.1 -80.0 88.0
27 0.544 56.61 70.0 88.0 0.544 386.1 -80.0 88.0
28 0.554 58.71 70.0 88.0 0.554 393.8 -80.0 88.0
29 0.563 60.80 70.0 87.9 0.563 401.1 -80.0 87.9
30 0.573 62.90 70.0 87.9 0.573 408.0 -80.0 87.9
31 0.583 65.00 70.0 87.8 0.583 414.5 -80.0 87.8
32 0.592 67.09 70.0 87.8 0.592 420.6 -80.0 87.8
33 0.601 69.19 70.0 87.8 0.601 426.4 -80.0 87.8
34 0.610 71.29 70.0 87.7 0.610 431.9 -80.0 87.7
35 0.619 73.38 70.0 87.7 0.619 437.0 -80.0 87.7
36 0.628 75.48 70.0 87.7 0.628 441.7 -80.0 87.7
37 0.636 77.58 70.0 87.6 0.636 446.0 -80.0 87.6
38 0.645 79.67 70.0 87.6 0.645 450.0 -80.0 87.6
39 0.653 81.77 70.0 87.5 0.653 453.6 -80.0 87.5
40 0.662 83.87 70.0 87.5 0.662 456.9 -80.0 87.5
41 0.670 85.96 70.0 87.5 0.670 459.8 -80.0 87.5
42 0.678 88.06 70.0 87.4 0.678 462.4 -80.0 87.4
43 0.686 90.16 70.0 87.4 0.686 464.6 -80.0 87.4
44 0.694 92.25 70.0 87.3 0.694 466.5 -80.0 87.3
45 0.702 94.35 70.0 87.3 0.702 468.0 -80.0 87.3
46 0.710 96.45 70.0 87.3 0.710 469.1 -80.0 87.3
47 0.717 98.54 70.0 87.2 0.717 470.0 -80.0 87.2
48 0.725 100.64 70.0 87.2 0.725 470.4 -80.0 87.2
49 0.732 102.74 70.0 87.1 0.732 470.5 -80.0 87.1
50 0.740 104.83 70.0 87.1 0.740 470.3 -80.0 87.1
Harmonic Order
Sector Circle
59
APPENDIX B‐15 –STERLING 138 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.265 10.62 70.0 86.3 0.265 157.2 65.0 86.3
3 0.325 15.93 70.0 87.4 0.325 217.2 -85.0 87.4
4 0.375 21.25 70.0 87.9 0.375 279.7 -85.0 87.9
5 0.419 26.56 70.0 88.2 0.419 344.1 -85.0 88.2
6 0.459 31.87 70.0 88.4 0.459 409.7 -85.0 88.4
7 0.496 37.18 70.0 88.6 0.496 475.9 -85.0 88.6
8 0.530 42.49 70.0 88.7 0.530 542.0 -85.0 88.7
9 0.563 47.80 70.0 88.7 0.563 607.8 -85.0 88.7
10 0.593 53.12 70.0 88.8 0.593 672.7 -85.0 88.8
11 0.622 58.43 70.0 88.8 0.622 736.5 -84.5 88.8
12 0.650 63.74 70.0 88.8 0.650 799.0 -84.0 88.8
13 0.676 69.05 70.0 88.8 0.676 860.0 -83.5 88.8
14 0.702 74.36 70.0 88.9 0.702 919.3 -83.0 88.9
15 0.726 79.67 70.0 88.9 0.726 976.9 -82.5 88.9
16 0.750 84.99 70.0 88.9 0.750 1032.7 -82.0 88.9
17 0.773 90.30 70.0 88.8 0.773 1086.7 -81.5 88.8
18 0.796 95.61 70.0 88.8 0.796 1138.8 -81.0 88.8
19 0.817 100.92 70.0 88.8 0.817 1189.0 -80.5 88.8
20 0.839 106.23 70.0 88.8 0.839 1237.4 -80.0 88.8
21 0.859 111.54 70.0 88.8 0.859 1283.8 -80.0 88.8
22 0.880 116.86 70.0 88.8 0.880 1328.5 -80.0 88.8
23 0.899 122.17 70.0 88.8 0.899 1371.2 -80.0 88.8
24 0.919 127.48 70.0 88.8 0.919 1412.2 -80.0 88.8
25 0.938 132.79 70.0 88.7 0.938 1451.3 -80.0 88.7
26 0.956 138.10 70.0 88.7 0.956 1488.7 -80.0 88.7
27 0.974 143.41 70.0 88.7 0.974 1524.3 -80.0 88.7
28 0.992 148.73 70.0 88.7 0.992 1558.1 -80.0 88.7
29 1.010 154.04 70.0 88.7 1.010 1590.3 -80.0 88.7
30 1.027 159.35 70.0 88.6 1.027 1620.7 -80.0 88.6
31 1.044 164.66 70.0 88.6 1.044 1649.4 -80.0 88.6
32 1.061 169.97 70.0 88.6 1.061 1676.5 -80.0 88.6
33 1.077 175.28 70.0 88.6 1.077 1702.0 -80.0 88.6
34 1.093 180.60 70.0 88.6 1.093 1725.8 -80.0 88.6
35 1.109 185.91 70.0 88.5 1.109 1748.0 -80.0 88.5
36 1.125 191.22 70.0 88.5 1.125 1768.6 -80.0 88.5
37 1.141 196.53 70.0 88.5 1.141 1787.6 -80.0 88.5
38 1.156 201.84 70.0 88.5 1.156 1805.1 -80.0 88.5
39 1.171 207.15 70.0 88.4 1.171 1820.9 -80.0 88.4
40 1.186 212.46 70.0 88.4 1.186 1835.3 -80.0 88.4
41 1.201 217.78 70.0 88.4 1.201 1848.1 -80.0 88.4
42 1.215 223.09 70.0 88.4 1.215 1859.4 -80.0 88.4
43 1.230 228.40 70.0 88.3 1.230 1869.1 -80.0 88.3
44 1.244 233.71 70.0 88.3 1.244 1877.4 -80.0 88.3
45 1.258 239.02 70.0 88.3 1.258 1884.1 -80.0 88.3
46 1.272 244.33 70.0 88.3 1.272 1889.4 -80.0 88.3
47 1.286 249.65 70.0 88.2 1.286 1893.2 -80.0 88.2
48 1.299 254.96 70.0 88.2 1.299 1895.5 -80.0 88.2
49 1.313 260.27 70.0 88.2 1.313 1896.3 -80.0 88.2
50 1.326 265.58 70.0 88.2 1.326 1895.7 -80.0 88.2
Harmonic Order
Sector Circle
60
APPENDIX B‐16 –BAGATELLE 138 KV BUS HARMONIC IMPEDANCE PARAMETERS
Rmin Zmax Anglemin Anglemax Rmin Radius Anglemin Anglemax
(ohms) (ohms) (deg.) (deg.) (ohms) (ohms) (deg.) (deg.)
2 0.220 11.38 70.0 86.4 0.220 172.6 65.0 86.4
3 0.269 17.07 70.0 87.5 0.269 237.3 -85.0 87.5
4 0.311 22.76 70.0 88.0 0.311 304.2 -85.0 88.0
5 0.347 28.46 70.0 88.3 0.347 372.8 -85.0 88.3
6 0.380 34.15 70.0 88.5 0.380 442.4 -85.0 88.5
7 0.411 39.84 70.0 88.6 0.411 512.4 -85.0 88.6
8 0.439 45.53 70.0 88.7 0.439 582.3 -85.0 88.7
9 0.466 51.22 70.0 88.7 0.466 651.6 -85.0 88.7
10 0.491 56.91 70.0 88.8 0.491 720.1 -85.0 88.8
11 0.515 62.60 70.0 88.8 0.515 787.4 -84.5 88.8
12 0.538 68.29 70.0 88.8 0.538 853.4 -84.0 88.8
13 0.560 73.98 70.0 88.8 0.560 917.8 -83.5 88.8
14 0.581 79.67 70.0 88.8 0.581 980.5 -83.0 88.8
15 0.602 85.37 70.0 88.8 0.602 1041.6 -82.5 88.8
16 0.621 91.06 70.0 88.8 0.621 1100.8 -82.0 88.8
17 0.640 96.75 70.0 88.8 0.640 1158.1 -81.5 88.8
18 0.659 102.44 70.0 88.8 0.659 1213.5 -81.0 88.8
19 0.677 108.13 70.0 88.8 0.677 1267.1 -80.5 88.8
20 0.695 113.82 70.0 88.8 0.695 1318.7 -80.0 88.8
21 0.712 119.51 70.0 88.8 0.712 1368.5 -80.0 88.8
22 0.728 125.20 70.0 88.8 0.728 1416.3 -80.0 88.8
23 0.745 130.89 70.0 88.8 0.745 1462.2 -80.0 88.8
24 0.761 136.58 70.0 88.8 0.761 1506.3 -80.0 88.8
25 0.777 142.28 70.0 88.7 0.777 1548.5 -80.0 88.7
26 0.792 147.97 70.0 88.7 0.792 1588.8 -80.0 88.7
27 0.807 153.66 70.0 88.7 0.807 1627.4 -80.0 88.7
28 0.822 159.35 70.0 88.7 0.822 1664.0 -80.0 88.7
29 0.836 165.04 70.0 88.7 0.836 1698.9 -80.0 88.7
30 0.851 170.73 70.0 88.6 0.851 1732.1 -80.0 88.6
31 0.865 176.42 70.0 88.6 0.865 1763.4 -80.0 88.6
32 0.879 182.11 70.0 88.6 0.879 1793.0 -80.0 88.6
33 0.892 187.80 70.0 88.6 0.892 1820.8 -80.0 88.6
34 0.906 193.49 70.0 88.6 0.906 1846.9 -80.0 88.6
35 0.919 199.19 70.0 88.5 0.919 1871.3 -80.0 88.5
36 0.932 204.88 70.0 88.5 0.932 1894.1 -80.0 88.5
37 0.945 210.57 70.0 88.5 0.945 1915.1 -80.0 88.5
38 0.957 216.26 70.0 88.5 0.957 1934.4 -80.0 88.5
39 0.970 221.95 70.0 88.4 0.970 1952.1 -80.0 88.4
40 0.982 227.64 70.0 88.4 0.982 1968.1 -80.0 88.4
41 0.994 233.33 70.0 88.4 0.994 1982.4 -80.0 88.4
42 1.007 239.02 70.0 88.4 1.007 1995.2 -80.0 88.4
43 1.018 244.71 70.0 88.3 1.018 2006.3 -80.0 88.3
44 1.030 250.41 70.0 88.3 1.030 2015.7 -80.0 88.3
45 1.042 256.10 70.0 88.3 1.042 2023.6 -80.0 88.3
46 1.053 261.79 70.0 88.3 1.053 2029.8 -80.0 88.3
47 1.065 267.48 70.0 88.3 1.065 2034.5 -80.0 88.3
48 1.076 273.17 70.0 88.2 1.076 2037.5 -80.0 88.2
49 1.087 278.86 70.0 88.2 1.087 2039.0 -80.0 88.2
50 1.098 284.55 70.0 88.2 1.098 2038.8 -80.0 88.2
Harmonic Order
Sector Circle
61
APPENDIX C
Loss Evaluation Duty Cycles
62