Download Proposed New ISO Rules Part 500, Facilities Division 502, Technical Requirements

Proposed New ISO Rules
Part 500, Facilities
Division 502, Technical Requirements
Section 502.5
Generating Unit
Technical Requirements
ISO Rules
Part 500 Facilities
Division 502 Technical Requirements
Section 502.5 Generating Unit Technical
Requirements
External Consultation Draft
Version 12.0
December 6, 2011
Draft of New ISO Rules Text
November 29, 2012
Applicability
1
This sectionSection 502.5 applies to:
(a) the legal owner of a generating unit that is:
(i) synchronous; and
(ii) directly connected to the transmission system or the City of Medicine Hat;
including:
(iii) a generating unit situated within an industrial complex that is directly connected to the
transmission system;
but not including:
(iv) any wind aggregated generating facilities;
(b) the legal owner of a transmission facility; and
(c) the ISO.
Requirements
New Generating Unit
2(1)
On and after the effective date of this section 502.5 and subject to the provisions of this
subsection 2, the legal owner of a generating unit which is new as of the effective date must comply
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Section 502.5 Generating Unit Technical
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with the provisions of this section 502.5 prior to the generating unit being energized, and must continue
to comply for so long as the generating unit remains connected to the transmission system.
(2) The testing, reporting and modeling requirements set out in subsections 24 to 28 do not apply to a
new generating unit that is connected to the in-plant distribution of an industrial complex and with two (2)
or more voltage transformations between the generating unit terminals and the transmission system.
(3) The reactive power requirements of a power purchase arrangement set out in subsection 9 do
not apply to a new generating unit.
(4) If after the effective date of this section 502.5 the legal owner of a new generating unit
subsequently modifies any facilities of the generating unit, then subject to subsections 2(2) and 2(3) the
legal owner must ensure the facilities modification is in compliance with the provisions of this section
502.5.
(5) The provisions of this section 502.5 do not apply to a new generating unit with a functional
specification the ISO issued prior to the effective date of this section 502.5, but the new generating unit
must remain in compliance with the functional specification including all of the standards and
requirements referenced in the functional specification.
Existing Generating Unit
3(1) On and after the effective date of this section 502.5 and subject to the provisions of this subsection
3, the legal owner of a generating unit which is in existence, energized and in commercial operation as
of the effective date must comply with the provisions of this section 502.5 and with the functional
specification provisions for the existing generating unit, and must continue to comply for so long as the
generating unit remains connected to the transmission system.
(2) The testing, reporting and modeling requirements set out in subsections 24 to 28 do not apply to an
existing generating unit that is connected to the in-plant distribution of an industrial complex and with two
(2) or more voltage transformations between the generating unit terminals and the transmission
system.
(3) The synchronized phasor measurement system provisions set out in subsection 21 do not apply to
an existing generating unit.
(4) If after the effective date of this section 502.5 the legal owner of an existing generating unit
subsequently modifies any facilities of the generating unit, then subject to subsection 3(2) the legal
owner must ensure the facilities modification is in compliance with the provisions of this section 502.5.
Functional Specification
42(1) The ISO must, in accordance and generally consistent with this section 502.5 and any other
applicable ISO rules, approve of a functional specification containing further details, work requirements,
and specifications for the design, construction and operation of a generating unit connection project and
any associated transmission system connection facilities.
(2) The functional specification for the generating unit referred to in subsection 42(1) must be
generally consistent with the provisions of this section 502.5, but may contain material variances the ISO
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approves of based upon its discrete analysis of any one (1) or more of the technical, economic, safety,
operational and reliability requirements of the interconnected electric system related to the specific
connection project.
Successor to Prior Requirements
53
Subject to subsectionssubsection 2 and 3, this section 502.5 succeeds and replaces sections 1.0,
2.0 and 3.0 as they relate to generation of the Generation and Load Interconnection Standard which
came into effect as of September 19, 2006 and that standard, together with any other prior standards or
drafts of standards on the subject matter, no longer will be in force and effect as of the effective date of
this section 502.5.
Operating Voltage Requirements
6(1)
The legal owner of a new or modified existing generating unit must submit in writing to the ISO
the two (2) root mean square phase-to-phase operating voltage values the legal owner proposes to be
used for the generating unit:
(a)
the first value at the point of connection of the generating unit to the transmission
system, based on the normal operating voltage levels at the specific location of the
generating unit; and
(b)
the second value at the terminals of the generating unit.
(2)
Once the ISO receives and approves of the operating voltage values proposed by the legal owner,
or alternative operating voltage values required by the ISO for the generating unit, then the ISO must set
out the operating voltage values in the functional specification for the generating unit.
(3)
The legal owner of an existing generating unit must, upon receipt of a written notice from the ISO,
submit in writing to the ISO for its approval the proposed operating voltage values in accordance with
th
subsection 6(1) no later than the close of business on the thirtieth (30 ) business day after delivery of
the notice.
(4)
The ISO must make a decision on its approval and notify the legal owner in writing of the decision
no later than ninety (90) days after the date of receiving the submission from the legal owner.
(5)
Once the ISO approves of the operating voltage values under this subsection 6, then the ISO must
use the operating voltage values for the generating unit to determine under this section 502.5:
(a)
the voltage ride-through requirements;
(b)
the voltage regulation; and
(c)
the reactive power requirements.
Maximum Authorized Real Power
74(1) The legal owner of a new or modified existing generating unit must submit in writing to the ISO a
proposeddetermine the maximum authorized real power value for the generating unit, and once the
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ISO receives and approves.
(2)
The legal owner of the proposed value, the ISO must set it out in the functional specification for the
a generating unit.
(2)
The must consider the following when determining the maximum authorized real power value
the ISO approves of must also be in :
(a) compliance with the reactive power requirements set out in subsection 7;
(b) compliance with all other subsections 8 or 9, as applicable.of this section 502.5; and
(c) turbine and stator winding capability or limitations under optimal conditions.
(3) The ISO must deem the maximum authorized real power for an existinga generating unit to be
the ”maximum authorized MW” the ISO previously approved in writing or in the functional specification for
the generating unit but only if the generating unit continues to meet all conditions of that approval.
(4)
A generating unit must not be operated in excess of its maximum authorized real power.
Reactive Power Requirements for Aa Generating Unit
85(1) The reactive power requirements forlegal owner of a generating unit must be based
ondetermine the operatingroot mean square phase-to-phase voltage value submitted under subsection
6(1) (b) and approved of by the ISO under subsection 6(2), as measured at the stator winding terminals of
the generating unit to be used as the one hundred percent (100%) voltage value to determine the
reactive power requirements for the generating unit.
(2) The generating unit and any approved external reactive power resources must have the
capability to operate in accordance with subsection 85(3) by both:
(a) manual control of the set point of the automatic voltage regulator of the generating unit; and
(b) automated action of the automatic voltage regulator of the generating unit.
(3) The reactive power capability of the generating unit must be in compliance with the following
minimum requirements:
(a) zero point nine (0.9) power factor, over-excited; and
(b) zero point nine five (0.95) power factor, under-excited;
as illustrated by the rectangular shaded area of Appendix 1 and based on the maximum authorized real
power of the generating unit over the entire real power operating range, down to the applicable
minimum gross real power that the generating unit can achieve without any additional wear and tear
beyond normal operation.
(4(4) The generating unit, subject to subsections 5(5), must not have limiters set to reduce the reactive
power capability set out in subsection 5(3).
(5)
The legal owner of a generating unit with the capability to meet the reactive power requirements
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Section 502.5 Generating Unit Technical
Requirements
of this subsection 8, as demonstrated by the data and records submitted under subsection 23(3) may5
but which has stability concerns must submit in writing to the ISO:
(a) a request for approval of a proposed reduction in the reactive power capability requirement set
out in subsection 85(3)(b) and Appendix 1 due to generating unit stability concerns; and
(b) a detailed study in support of the request which is specific for the generating unit at its location
and completed by a qualified professional engineer, demonstrating the reactive power
capability set out in subsection 85(3)(b) should be reduced by a limiter because that reactive
power capability will cause the generating unit to become unstable.
(56) The ISO must make a decision on its approval and notify the legal owner in writing of the decision
no later than ninety (90) days after the date of receiving the submission.
(6) If based on the request and the study contents the ISO approves of the proposed reduced reactive
power capability, then the ISO must set out the reduced reactive power capability in the functional
specification for the generating unit.subsection 5(5).
(7) The legal owner of a generating unit without the capability to meet the reactive power capability
as demonstrated by the data submitted under subsection 23(3) must submit to the ISO a request in
writing for approval of the use of an external dynamic reactive power resource to compensate for the
lack of capability, and if such that the request is approved, then the ISO must set out the usecombined
capability of the generating unit and external dynamic reactive power resource in the functional
specification for the generating unit. meets the requirements of subsection 5(3).
Additional Reactive PowerVoltage Ride-Through Requirements for aExisting Generating UnitUnits
6(1) This subsection 6 applies to the legal owner of a generating unit without a functional specification
referencing this section 502.5 and which:
(a) has a maximum authorized real power greater than nine (9) MW; or:
(b) is a part of a complex with a Power Purchase Arrangementother generating units with an
aggregate maximum authorized real power amount greater than nine (9) MW.
9(1(2) The legal owner of a generating unit that is subject to the reactive power must determine the
root mean square phase-to-phase voltage value at the high voltage side of the transmission system
step-up transformer to be used as the one hundred percent (100%) voltage value to determine the
voltage ride-through requirements of a power purchase arrangement must ensure the generating unit
is in compliance with the additional reactive power requirements set out in this subsection 9.
(2) The generating unit must have existing power factor information derived from the reactive power
capability curves in the power purchase arrangement of the for the generating unit, as illustrated in
.Appendix 2.
(3)
Under normal operating conditions, a hydro generating unit must be capable of the requirements
specified in subsection 8.
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(4)
Under normal operating conditions, a thermal generating unit must have the capability of
complying with a reactive power or voltage level directive within the levels in Schedule B of the power
purchase arrangement of the generating unit.
(5)
Under abnormal or system emergency conditions, a thermal generating unit and any approved
external reactive power resources must have the capability to operate beyond the limits in Schedule B of
the power purchase arrangement up to the values specified in subsection 9(6) by both:
(a)
manual control of the set point of the automatic voltage regulator of the generating unit;
and
(b)
automated action of the automatic voltage regulator of the generating unit.
(6) Under abnormal or system emergency conditions, the reactive power capability of a thermal
generating unit must be in compliance with the following minimum requirements:
(a)
zero point nine (0.9) power factor, over-excited; and
(b)
zero point nine five (0.95) power factor, under-excited;
as illustrated by the rectangular shaded area of Appendix 2, and based on the maximum authorized real
power of the generating unit over the entire real power operating range, down to the applicable
minimum gross real power that the generating unit can achieve without any additional wear and tear
beyond normal operation.
(7)
The legal owner of a generating unit that is the subject of a power purchase arrangement may
submit a request for a proposed reduction in the reactive power capability set out in subsection 9(6)(b)
and Appendix 2, complying with the submission requirements set out in subsections 8(4) through 8(6).
(8)
If a generating unit that is the subject of a power purchase arrangement undergoes a facilities
modification which increases the real power output to an amount in MW which is in excess of the
maximum authorized real power referenced in subsection 7, then the ISO will deem the modification to
generate MW output beyond the power purchase arrangement committed capacity, plus two percent
(2%).
(9)
If there is an increase in the real power capability of the generating unit due to the facilities
modification referenced in subsection 9(8), then the legal owner must ensure the generating unit is in
compliance with all provisions of this section 502.5, except subsections 9(2), 9(4) and 21.
(10) The legal owner of a generating unit that is the subject of a power purchase arrangement must
comply with the reactive power requirements of subsection 8 once the power purchase arrangement
expires.
Voltage Ride-Through Requirements
10(1) A generating unit must be capable of meeting the following voltage ride-through requirements:
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(a) continuous operation between ninety percent (90%) and one hundred and ten percent (110%)
of the operating voltage value submitted under subsection 6(1)(a) and approved of by the
ISOdocumented under subsection 6(2).); and
(2(b)
not tripping or going off-line during or as a result of a voltage dip or post-transient voltage
deviation resulting from a normally cleared disturbance on the transmission system on any
phase or combination of phases at or beyond the point of connection as illustrated in
Appendix 1.
(4) The normal clearing time used in subsection 6(3)(b) must be based on the specific location where
the generating unit is connected to the transmission system.
(5) Notwithstanding any other provision of this subsection 106, a generating unit is not required to
ride-through a transmission system fault that:
(a) causes a forced outage of a radial transmission line toconnecting the generating unit to the
transmission system;
(b) occurs on the generating unit side of the point of connection, including the lower voltage
network and the substation;
(c) results in a transfer trip or anti-islanding protection scheme to activate at the generating unit
which will cause the generating unit to be disconnected from the transmission system; or; or
(d) results inwhich will cause the generating unit becoming dynamically unstable due to be
disconnected from the transmission system instability.
(3)
Subject to Voltage Ride-Through Requirements for New Generating Units
7(1) This subsection 10(2),7 applies to the legal owner of an existinga generating unit with a
functional specification referencing this rule 502.5 and which:
(a) has a maximum authorized real power value equal to or greater than nine (9) MW must
ensure the ; or:
(b) is a part of a complex with other generating units with an aggregate maximum authorized
real power amount greater than nine (9) MW;
(2) The legal owner of a generating unit does not trip or go off-line for a transmission system
disturbance at or beyondmust determine the point of connection that results in a root mean square
phase-to-phase voltage excursion on the high voltage side ofvalue at the transmission system step-up
transformer: of the generating unit to be used as the one hundred percent (100%) voltage value to
determine the voltage ride through requirements for the generating unit.
(a)
as low as fifteen point zero percent (15.0%) that is cleared:
(i)
in normal clearing times specific to the location of the generating unit, for three (3)
phase faults; or
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(ii) in delayed clearing times specific to the location of the generating unit, for single phase
to ground faults; or
(b)
as low as twenty percent (20%) for pre-disturbance conditions, for periods of up to
forty (40) cycles during the post fault transient period.
(4) The legal owner of an existing generating unit must ensure the following does not occur within
six hundred and twenty five (625) milliseconds of the transmission system disturbance inception or for
the post–fault transient period:
(a)
protection functions pick-up, time out and result in the generator or any other critical device
tripping;
(b)
contactors drop out causing a critical device to go off line;
(c)
critical motors stall; or
(d)
other conditions that will result in the generating unit going off-line as a direct result of the
voltage disturbance.
(5) Subject to subsection 10(2), the(3)
The legal owner of a new generating unit with a
maximum authorized real power value equal to or greater than nine (9) MW must ensure the
generating unit is in compliance with capable of meeting the following voltage ride-through requirements:
(a) continuous operation between ninety percent (90%) and one hundred and ten percent (110%)
of the generating unit must voltage value documented under subsection 7(2); and
(a)(b)
not triptripping or gogoing off-line during or as a result of a voltage dip or post-transient
voltage excursiondeviation resulting from a normally cleared transmission system
disturbance on any phase or combination of phases at or beyond the point of connection as
illustrated in Appendix 32; and
(b)(c)
the time that the voltage remains at zero point zero percent (0.0%) must be based on the
normal clearing time for a three (3) phase fault at the specific location ofwhere the generating
unit is connected to the transmission system.
(4)
The normal clearing time used in subsection 7(3)(b) must be based on the specific location where
the generating unit is connected to the transmission system.
(5)
Notwithstanding any other provision of this subsection 7, a generating unit is not required to ridethrough a transmission system fault that:
(a)
causes a forced outage of a radial transmission line connecting the generating unit to the
transmission system;
(b)
occurs on the generating unit side of the point of connection, including the lower voltage
network and the substation; or
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Section 502.5 Generating Unit Technical
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(c)
results in a transfer trip or anti-islanding protection scheme to activate at the generating unit
which will cause the generating unit to be disconnected from the transmission system.
Automatic Voltage Regulator
118(1) A generating unit must have a continuously variable, continuously acting, closed loop,
centralized automatic voltage regulator that measurescompares a measured voltage compared to a set
point, and must control reactive power devices and any dynamic reactive power resources needed to
meet the requirements underof this section 502.5.
(2)
The automatic voltage regulator must:
(a) be designed to be continuously in service and controlling while the generating unit is
connected to the transmission system, regardless of the quantity of real power output from
the generating unit under both non-disturbance and disturbance conditions;
(b) be capable of operating in a voltage set point control mode to the exclusion of any other
modes;
(c) be capable of manual set point adjustments to a percentage between ninety five percent
(95%) and one hundred and five percent (105%) of the operating voltage value
submitteddetermined under subsection 6(1)(b) and approved of by the ISO under subsection
6(2); and
(d) in combination with the generating unit facilities be able to achieve, under non-disturbance
conditions, a steady state voltage regulation of plus or minus zero point five percent (+/- 0.5%)
of the voltage set point at the point of control which, subject to subsections 11(48(3) through
11(108(6), is at the stator winding terminals of the generating unit.
(3)
Subject to subsection 11(4), the ISO must assess voltage regulation performance at the point of
control.
(4) The legal owner of thea generating unit may submit a request in writing to the ISO for approval of
a point of control beyond theto use a reactive current compensation feature in the automatic voltage
regulator to adjust the point of control to be other than the stator winding terminals of the generating
unit, and if based on the request the ISO approves the proposed point of control then the ISO must set
out the alternative point of control in the functional specification for the generating unit..
(54) The ISO must make a decision on its approval and notify the legal owner in writing of the decision
no later than ninety (90) days after the date of receiving the submission. set out in subsection 8(3).
(6)
For a generating unit that does not share a common bus with other generating units, the point of
control for the automatic voltage regulator must not be within the generating unit.
(7(5) The point of control for the automatic voltage regulator must not be at the high voltage side of the
transmission system step-up transformer.
(86) If there arethe stator winding terminals of two (2) or more generating units connected to a
common bus with no significant impedance between the generating unitsstator winding terminals, then
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Section 502.5 Generating Unit Technical
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the automatic voltage regulator of each generating unit must be capable of reactive current
compensation such that the point of control is within the impedance of the generating units.
(97) If the automatic voltage regulators of two (2) or more generating units have a common
measurement point, then there must be reactive power current compensation in each automatic voltage
regulator, and the ISO must approve the value of the reactive power current compensation and set it
out in the functional specification for the generating unit.
(10) The ISO may, upon no less than ninety (90) days notice in writing to the legal owner of a
generating unit, require a change by the specified date to the settings of the reactive power current
compensation gain or the reactive power current compensation settings of the generating unit.
(11(8) Stator current limiters are prohibited for a generating unit.
Frequency and Speed Governing Requirements
129(1) A generating unit with a maximum authorized real power ofequal to or greater than ten (10)
MW or more must be in compliance with the governor system and frequency and speed governing
requirements set out in this subsection 12.
(2)
The generating unit must have a continuously acting governor system, which must:
be designed :
(a) to be continuously in service, controlling and free to respond to frequency changes while the
generating unit is connected to the transmission system and regardless of the quantity of
real power output from the generating unit;
(b) be capable of with a droop setting of the droop equal to or greater than three percent (3%) but
less than or equal to five percent (5%), and the default setting must be five percent (5%);%);
(c) havewith a deadband, intentional plus unintentional, which must not exceedexceeding plus or
minus zero point zero three six (0.036) Hz; and
(d) with the capability, in combination with the generating unit facilities, be capable of manual
setpoint adjustments within a range of fifty -nine point four (59.4) Hz and sixty point six (60.6)
Hz.
(3)
If the frequency of the generating unit while connected to the transmission system remains
greater than sixty one point seven (61.7) Hz or less than fifty seven (57) Hz for more than ten (10)
minutes, then the generating unit must be immediately removed from service.
(4(2) The generating unit must be able to accommodate not trip for under-frequency and overfrequency excursionsdeviations for the minimum time frames as set out in Appendix 43.
(53) Notwithstanding any other provision of this section 502.5,subsection 9(2), a generating unit that
trips off in a shorter period than the minimum time set forth in Appendix 43 must have binding and firm
arrangements to automatically and simultaneously trip off an amount of load in MW on the
interconnected electric system equal to the anticipated generation loss in MW, at comparable
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frequency levels.
Power System Stabilizer
1310(1) If the excitation system for an existinga generating unit :
(a) has been modifieda maximum authorized real power greater than twenty-seven (27) MW; or
(b) is a part of a complex with other generating units with an aggregate maximum authorized
real power amount greater than sixty-seven point five (67.5) MW;
then a power system stabilizer must be installed on each generating unit.
(2) If the legal owner of a generating unit replaces the exciter or automatic voltage regulator on a
planned basis at any time after November 18, 1993 and the generating unit:
(a) has a maximum authorized real power greater than twenty-seven (27.0) MW; or
(b) is a part of an industriala complex with other generating units with an aggregate maximum
authorized real power amount greater than sixty-seven point five (67.5) MW;
then a power system stabilizer must be installed on the existingeach generating unit.
(2)
If a new or modified existing generating unit:
(a)
has a maximum authorized real power greater than 27.0 MW; or:
(b)
is a part of an industrial complex with other generating units with an aggregate maximum
authorized real power amount greater than 67.5 MW;
then a power system stabilizer must be installed on the generating unit.
(3) A(3)
Notwithstanding subsection 11(1) and 11(2), a power system stabilizer is not required
to be installed on a generating unit if the closed loop phase lag between the generating unit
terminalstator winding terminals voltage and the automatic voltage regulator reference input is greater
than one hundred and thirty five degrees (135).
(4) If a pump storage generating unit is equipped with a power system stabilizer and is capable of
operating in the pump mode while connected to a transmission system such that the power system
stabilizer does not produce negative damping, then the power system stabilizer must be designed to
be in service in the pump mode.
(5)
A power system stabilizer must:
(a) be designed to be in continuous operation while the generating unit is on-line except for when
the generating unit is producing less real power than its design limit for effective power
system stabilizer operation;
(b) be reviewed and retuned if any automatic voltage regulator response parameters for the
generating unit are modified;
(c) be either:
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(c)(i) a dual input integral of accelerating real power type; or
(ii) a single input speed or frequency type;
(d) provide a compensated frequency response of the excitation system and generating unit such
that, through the frequency range from zero point one (0.1) Hz to one point zero (1.0) Hz, the
phase shift will not exceed plus or minus thirty (±30) degrees;
(e) be capable of output limits between plus or minus five percent (±5%) of the operating voltage
value submitted under subsection 6(1)(b) and be approved of by the ISO under subsection
6(2); and
(f) have the gain set to provide a gain margin of no less than six (6) dB and no more than ten (10)
dB; and
(g) have the washout time constant set as low as possible while maintaining the compensated
phase criteria.
(6)
A power system stabilizer of the real power type is prohibited for a generating unit.
Transmission System Step-Up Transformer
1411(1) The capability of the transmission system step-up transformer design offor a generating unit
must be such that the real power and reactive power requirements specified in this section 502.5 are
fully available throughout anythe continuous operating voltage range set out in the functional specification
for the generating unit, and the design must includeconsider the generating unitfollowing parameters:
(a) thermal ratingcapability of:
(i) bushings;
(ii) windings; and
(a)(iii) tap changer;
(b) voltage ratio;
(c) tap changer type; and
(d) tap changer range; and.
(e)
tap changer step size.
(2) The legal owner of a generating unit may subtract the amount in MW of auxiliary and excitation
system load of the generating unitin apparent power from the MWapparent power capability of the
generating unit at the maximum authorized real power to determine the net real power and reactive
power requirements of the transmission system step-up transformer referred to in subsection 1411(1),
but only if any of that auxiliary and excitation system load is connected between the generating unit
stator winding terminals and the transmission system step-up transformer.
(3)
Subject to subsection 1411(4), the transmission system step-up transformer winding connections
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for a generating unit must provide for:
(a) a favourable circuit to block the transmission of harmonic currents;
(b) isolation of transmission system and generating unitlow voltage side ground fault current
contributions;
(c) an effectively grounded wye connection on the high voltage side of the transformer; and
(d) on-load or off-load tap changers with a minimum capability of plus or minus five percent (5%)
voltage range in two point five percent (2.5%) increments.
(4)
AsThe legal owner of the effective date ofa generating unit:
(a) without a functional specification referencing this section 502.5 an existing generating unit ;
and
(b) with a transmission system step-up transformer that does not comply with the requirements of
subsection 14(3) is exempt from the requirements, but if at any time after that effective date the
transmission system step-up transformer is replaced, then the legal owner must ensure the
replacement equipment complies with subsection 14(3).11(3);
is exempt from complying with subsection 11(3), but if at any time after the effective date of this section
502.5, the transmission system step-up transformer is replaced on a planned basis, then the legal
owner must ensure the replacement equipment meets the requirements of subsection 11(3).
Auxiliary Systems
1512(1) A new or modified existingWithin facilities with multiple generating units:
(a) each generating unit must have independent auxiliary systems which will operatedesigned so
that no single auxiliary system equipment the failure will cause multiple generating units to
tripof a single component will not result in the simultaneous tripping or shutdown of two (2) or
go off-line.more generating units;
(b) staggered shutdowns must have timeframes of greater than ten (10) minutes; and
(c) for combined cycle plants, the loss of the combustion turbine that results in the tripping of the
steam turbine is acceptable.
(2) The design of the auxiliary systems must be in compliance with consider the voltage ride-through
requirements of as specified in the applicable subsection 106 or 7.
(3) The legal owner of a generating unit without a functional specification referencing this section
502.5 but with auxiliary systems that do not comply with the requirements of subsection 12(1) is exempt
from complying with subsection 12(1).
Generating Unit Disconnection and Interrupting Devices
1613(1) The legal owner of the generating unit and the legal owner of the transmission facility to
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Section 502.5 Generating Unit Technical
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which the generating unit is connected must ensure as between them that there are circuit breakers
and controls which electrically disconnect the generating unit from the transmission system at either
or boththe point of: connection.
(2)
(a)
the point of connection; and
(b)
the terminal of the generating unit.
The circuit breaker operationsdesign for the generating unit must:
(a)
account for the present and future fault current contributions from both the transmission system
and the generating unit facilities; .
(b)
(c)
have fault interrupting and momentary withstand ratings as specified in the functional
specification for the generating unit ; and
not have fault interrupting devices that (3) The use of fuses at sixty (60) kV or higher is prohibited.
(3) The determination of the responsibility for circuit breakers and controls must be set out in the
functional specification for the generating unit.
Isolating Devices
1714(1) The legal owner of a generating unit and the legal owner of the transmission facility to which
the generating unit is connected must ensure as between them that the generating unit has a
minimum of one (1) isolation device with manual operation capability at a point of isolation.
(2) The isolation device must permit visual verification of electrical isolation and have the capability of
being locked open with multiple locks.
(3) The determination of the responsibility for isolation devices must be set out in the functional
specification for the generating unit.
(4)
The legal owner of the generating unit and the legal owner of the transmission facility must
agree upon and specify one (1) or more points of isolation.
(5(3) All isolating devices must be under the control of a single control authority as agreed to between
the legal owner of the generating unit and the legal owner of the transmission facility, and the
agreed to control authority must be confirmed in a joint operating agreement.
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Section 502.5 Generating Unit Technical
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(4)
The isolation device must permit the installation of temporary safety grounding so that either side
can be safely maintained when the other side is energized.
(5) The legal owner of a generating unit without a functional specification referencing this section
502.5 is exempt from the requirements of subsection 14(4).
Power Quality
1815(1) The voltage flickergenerating unit must be designed to meet the following power quality
requirements:
(a) the induced by a generating unit voltage as measured at the point of connection must :
(i) be in compliance with the specifications set out in the version of the International
Electrotechnical Commission 61000-3-7, Electromagnetic compatibility (EMC) – Part 3-7:
Limits - Assessment of emission limits for the connection of fluctuating installations to MV,
HV and EHV power systems that:
(A) for a generating unit with a functional specification referencing this section 502.5, is in
effect as of the date the ISO first approves of the functional specification for the
generating unit connection project.; or
(B) (2) Withoutfor a generating unit without a functional specification referencing this
section 502.5, was in effect as of September 19, 2006; and
(ii) without limiting the generality of subsection 18(2), the generating unit must15(1)(a)(i), be
in compliance with the short and long term flicker limits as set out in the following Table 1:
Table 1
Short and Long Term Flicker Limits
≤ 25kVEmission
Limit
0.9
Pst
0.7
Plt
> 25kV
0.8
0.6
where:
Pst is the magnitude of the resulting short term flicker level for the considered
aggregation of flicker sources (probabilistic value);
Plt is the magnitude of the resulting long term flicker level for the considered aggregation
of flicker sources (probabilistic value));
(3)
Upon receipt of a written request from the legal owner of a new or modified existing generating
unit, the ISO must provide a description of the specific harmonic-impedance envelope at a proposed
point of connection for the generating unit.
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Section 502.5 Generating Unit Technical
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(4) The generating unit(b)
it must be in compliance with the specifications set out in the
version of the IEEE Standard 519, Recommended Practices and Requirements for Harmonic
Control in Electrical Power Systems – Section 11 that:
(i) for a generating unit with a functional specification referencing this section 502.5, is in
effect as of the date the ISO first approves of the functional specification for the generating
unit connection project, and all measurements must be at the point of connection. ; or
(5) The generating unit (ii) for a generating unit without a functional specification
referencing this section 502.5, was in effect as of September 19, 2006;
(b) all measurements must be at the point of connection;
(c) must not introduce any resonance into the transmission system, including self-excitation of
induction machines, transformer ferroresonance, resonant effects of capacitor additions and the
capacitance of the cables of the generating unit.;
(6) The generating unit(d)
it must not increase the phase-to-phase voltage unbalance of the
transmission system by more than one percent (1.0%), as measured at the point of
connection. ; and
(7) Thee) the voltage imbalance percentage requirement referenced in subsection 18(615(1)(d)
must be based on normal operating conditions for ninety five percent (95%) of the time over
any continuous seven (7) day measurement period, calculated in accordance with the following
formula:
Voltage Unbalance =
100 x deviation from average
Average
Grounding
1916 The legal owner of a generating unit must design, engineer and construct the generating unit to
take into account that the transmission system operates as an effectively grounded system.
Lightning and Other Surge Protection
2017(1) A generating unit must have surge protection for any associated substation equipment, and the
conditions under which the surge protection must operate include:
(a) lightning, including the average isokeraunic level for the generating unit location;
(b) switching surges;
(c) neutral shifts;
(d) electrical islands; and
(e) temporary over-voltages.
(2)
The surge protection for the generating unit must be compatible with the connecting transmission
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Section 502.5 Generating Unit Technical
Requirements
facility to ensure coordination of insulation levels.
Synchronized PhasorSynchrophasor Measurement System
2118(1) A new generating unit or an existing generating unit that undergoes a modification replacing
the protection system must have a synchronized phasorsynchrophasor measurement system in
compliance with the specifications contained in the version of the AESO Requirements for Phasor
Measurement Units referenced in the functional specification the ISO first approves of for the generating
unit connection projectany related synchrophasor measurement system rule or standard.
(2) Synchronized phasorSynchrophasor measurements must be maderecorded at the following
locations:
(a) at the stator winding terminal of the generating unit for all three (3) phase-to-ground voltages
and currents; and
(b) at the high side of the step-up transformer of the generating unit for all three (3) phase-toground voltages and currents.
(3)
The legal owner of the generating unit must comply with requirements for reporting synchronized
phasor measurements as the ISO designates in the functional specification for the generating unit,
which reporting requirements must be either:
(a)
thosedesign a system that is capable of downloading and retaining the recordings set out in
the AESO Requirements for Phasor Measurement Units document; or
(b)
in accordance with a written notice from the ISO to the legal owner requiring the legal
th
owner to submit the records no later than the close of business on the (5 ) business day
after delivery of the notice by the ISO.
(4) The legal owner of the generating unit must retain the recordssubsection 18(2) for a period of one
(1) calendar year from the date of the initial recording. unless the ISO otherwise designates in the
functional specification for the generating unit,
(4)
As of the effective date of this section 502.5 the legal owner of any generating unit without a
functional specification referencing this section 502.5 is exempt from the requirements of this subsection
18 but if at any time after that effective date the protection system is replaced on a planned basis, then
the replacement equipment must include a synchrophasor measurement system that meets the
requirements of this subsection 18.
Internal Sequence of Event Monitoring
2219(1) Subject to subsection 22(319(4) a generating unit must have an internal sequence of event
monitoring system that initiates an event record for every event that results in a trip of the generating
unit, or for the status of key components, including if present:
(a) a governor system trip;
(b) an automatic voltage regulator trip, including:
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(i) over-excitation limiter action; and
(ii) under-excitation limiter action;
(c) a medium and low voltage switchgear and motor control centre protection trip;
(d) the status of key auxiliary components, including:
(i) Induced Draftinduced draft and Forced Draftforced draft fans;
(ii) boiler feed water pumps;
(ii) turbine inlet valves; and
(iv) medium and low voltage switchgear and motor control centres; and
(e) a mechanical protection trip.
(2) The legal owner of the generating unit must retain all event records the event monitoring design a
system initiatesthat is capable of downloading and retaining the recordings set out in subsection 19(1) for
no less than thirty (30) daysone (1) calendar year from the date of the initial recording.
(3(3) The sequence of event monitoring equipment must be synchronized to within one (1) millisecond of
the Coordinated Universal Time scale.
(4) As of the effective date of this section 502.5, an existingthe legal owner of a generating unit with
a functional specification referencing this section 502.5 with internal sequence of event monitoring
equipment that is incapable of monitoring and recording any specific event or component set out in
subsection 2219(1) is exempt from monitoring and recording of that specific event or equipment, but if at
any time after the effective date the sequence of event monitoring equipment is replaced, then the legal
owner of the generating unit must ensure the replacement equipment complies withmust meet the
monitoring and reporting requirements for the previously exempt event or equipment.of this subsection
19.
(4)
The sequence of event monitoring equipment must be synchronized to within one (1) millisecond of
the Coordinated Universal Time scale.
Submission of Data and Modeling Information
23(1) The legal owner of a new generating unit must submit to the ISO as required during the
connection process all data and records specified in this subsection 23 in a format the ISO
approves in accordance with that process.
(2)
The legal owner of a modified existing generating unit, upon receipt of a written notice from
the ISO, must submit to the ISO in a format the ISO approves all data and records specified in
subsection 23(3) plus any other data and records the ISO may reasonably request, no later than
th
the close of business on the sixtieth (60 ) business day after delivery of the notice.
(3)
The data and records referred to in subsection 23(2) include:
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Section 502.5 Generating Unit Technical
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(a)
the modeling data for the generating unit, and the transformers, control systems and other
generating unit installations;
(b)
the reactive power capability curve based on the operating voltage value submitted under
subsection 6(1) (b) and approved of by the ISO under subsection 6(2), and showing:
(i)
over-excitation limiters;
(ii)
under-excitation limiters; and
(iii)
any other limiting factors;
(c)
the VEE curve;
(d)
the exciter maximum continuous output; and
(e)
the minimum gross real power the generating unit can achieve without any additional wear
and tear beyond normal operation.
(4)
The legal owner of a new or modified existing generating unit must provide the ISO with a written
report which demonstrates that the generating unit is capable of meeting the voltage ride-through
requirements set out in subsection 10.
(5)
Subject to subsection 23(7), the legal owner must submit to the ISO a written report which
demonstrates that the generating unit is capable of meeting the voltage ride-through requirements set
out in subsection 9 if the ISO provides written notice to the legal owner stating there is evidence that the
actual performance of the generating unit does not correlate with the voltage ride-through requirements
set out in that subsection 10.
(6)
The legal owner upon receipt of the notice must submit the report no later than the close of
th
business on the sixtieth (60 ) business day after delivery of the notice.
(7)
The legal owner is not required to submit the report if, between the date the ISO delivers the
written notice and the deadline date for the submission of the written assessment, the legal owner
demonstrates to the satisfaction of the ISO that the lack of correlation was caused by equipment
problems for the generating unit that the legal owner corrected prior to the submission deadline date.
Testing Intervals
24(1) The legal owner of a generating unit:
(a)
with a maximum authorized real power equal to greater than nine (9) MW; or
(b)
that is part of a generating facility or industrial complex containing generating units with an
aggregated maximum authorized real power for all of the generating units equal to
greater than eighteen (18) MW;
must comply with the testing and reporting requirements set out in subsections 24, 26, 27 and 28.
(2) The legal owner of a new generating unit must complete all baseline testing of the generating
unit, including model validation of the control systems and reactive power verification testing, no later
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Section 502.5 Generating Unit Technical
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than ninety (90) days after the first day of synchronization of the generating unit to the transmission
system.
(3)
The legal owner of an existing generating unit that modifies any facilities in any manner set out
under subsection 24(4) must complete the testing requirements set out in subsection 24(2).
(4)
Modifications to an existing generating unit that require baseline testing include:
(a)
replacement or changes to control settings or software of:
(i)
the automatic voltage regulator;
(ii)
the power system stabilizer; or
(iii)
the governor system;
(b)
a generating unit stator rewind;
(c)
a rotary exciter rewind;
(d)
a turbine replacement; or
(e)
any other modification that changes the behaviour of the generating unit as a connected
facility to the transmission system.
(5)
If the legal owner of a generating unit modifies it in any manner that results in an increase in the
maximum authorized real power, then the legal owner must perform the baseline testing and reactive
power verification on the generating unit.
(6)
The legal owner referred to in subsection 24(8) is only required to perform baseline testing on
those portions of the models of the generating unit that are affected by the modifications set out in
subsection 24(4).
(7)
The legal owner of a generating unit must perform model revalidation testing on no later than five
(5) years from the date of the prior validation testing of each model for the generating unit.
(8)
Subject to subsection 24(10), the legal owner must perform model revalidation testing and
reactive power verification on a generating unit if the ISO provides written notice to the legal owner
stating there is evidence that the modeled response of the generating unit does not correlate with the
actual response.
(9)
The legal owner upon receipt of such a notice must provide the written results of the model
revalidation testing and reactive power verification, no later than the close of business on the sixtieth
th
(60 ) business day after delivery of the notice.
(10) The legal owner is not required to provide the revalidation testing results if, between the date the
ISO delivers the written notice and the deadline date for the submission of model revalidation testing
results, the legal owner demonstrates to the satisfaction of the ISO that the lack of correlation was
caused by equipment problems for the generating unit that the legal owner corrected prior to the
revalidation testing date.
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Section 502.5 Generating Unit Technical
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Reporting
25(1) The legal owner of a generating unit must submit all test results referred to in this section 502.5
in reports that meet the format and other requirements of the ISO document entitled, Requirements for
Model Validation.
(2)
Unless otherwise specified in this section 502.5, the legal owner of a generating unit must submit
a separate report to the ISO no later than one hundred and eighty (180) days after the date of completion
of each of:
(a)
the first synchronization of a new generating unit to the transmission system;
(b)
the first synchronization of an existing generating unit to the transmission system upon
completion of any facilities modification;
(c)
the in-service date of any increase maximum authorized real power of a generating unit
the ISO approves;
(d)
the completion of model revalidation testing; or
(e)
the completion of reactive power verification testing.
Baseline Testing
26(1) The legal owner of a generating unit must perform baseline testing to validate all generating unit
parameters, using the maximum authorized real power for the generating unit.
(2)
The baseline testing must include:
(a)
a generating unit open circuit saturation test;
(b)
a generating unit and turbine inertia test; and
(c)
a synchronous machine impedances and time constants test.
(3)
The legal owner must validate the exciter parameters of the generating unit in compliance with
the following requirements:
(a)
characteristics of the voltage regulator and the exciter must be from direct current to five (5)
Hz;
(b)
the test recordings must include generating unit terminal voltage, field voltage or exciter field
current for brushless excitation systems; and
(c)
all tests must be conducted with the excitation system in automatic voltage control.
(4)
If a generating unit is equipped with a rotary exciter, then the legal owner must validate the open
circuit saturation of the exciter.
(5)
If a generating unit is equipped with a power system stabilizer, then the tests of the power
system stabilizer must:
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Section 502.5 Generating Unit Technical
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(a)
identify the transfer function up to ten (10) Hz;
(b)
include a gain test that identifies the maximum overall system gain;
(c)
verify that the local mode oscillation damping has improved, or, at a minimum, has not been
degraded; and
(d)
demonstrate that the under-excitation limiter is not interacting with the power system
stabilizer in such a way that the damping level is reduced or instability is observed if the
generating unit is equipped with a non-take-over type under-excitation limiter.
(6)
The turbine-governor system parameters for the generating unit must be validated in compliance
with the following requirements:
(a)
the characteristics of the turbine-governor system must be from direct current to one (1) Hz;
(b)
an on-line speed reference step must be conducted;
(c)
a measurement must be conducted of turbine-governor system steady-state droop; and
(d)
a measurement must be conducted of the generating unit steady-state gross real power
versus gate or valve position.
(7)
The baseline testing of the generating unit must include the reactive power verification testing set
out in subsection 27.
(8)
For a generating unit equipped with over-excitation and under-excitation limiters, the behaviour of
the limiters must be verified in limiter curves by:
(a)
plotting the limiter curves on the reactive power capability curve for the generating unit up
to the maximum authorized real power; and
(b)
testing the operation of the limiter at a minimum of one (1) point on the curve.
Reactive Power Verification and Re-verification Testing
27(1) The legal owner of a generating unit must verify the reactive power capability of the generating
unit by coordinating the scheduling of all reactive power testing with the ISO, and must supply a test
plan in accordance with any applicable ISO rules.
(2)
The reactive power test plan for the generating unit must include:
(a)
a general description of the test;
(b)
the gross real power output at which the test will take place;
(c)
the maximum gross reactive power that the generating unit will be supplying; and
(d)
the maximum gross reactive power that the generating unit will be absorbing.
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Section 502.5 Generating Unit Technical
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(3)
Subject to subsection 27(4), for test purposes the legal owner of the generating unit must ensure
that the gross real power output of the generating unit is equal to the maximum authorized real
power.
(4)
The legal owner of the generating unit may conduct the reactive power test for the generating
unit at values other than the maximum authorized real power if:
(a)
ambient conditions do not allow the generating unit to achieve the maximum authorized
real power; or
(b)
there are transmission system limits on the ability of the generating unit to supply or
absorb reactive power.
(5)
If a circumstance set out in subsection 27(4) exists, then to verify the generating unit can meet the
reactive power requirements the legal owner must submit to the ISO the following data as part of
the reactive power test report:
(a)
a reactive power capability curve showing:
(i)
over-excitation limiters;
(ii)
under-excitation limiters; and
(iii)
any other limiting factors;
(b)
a VEE curve; and
(c)
an exciter maximum continuous output.
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Section 502.5 Generating Unit Technical
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Model Revalidation Testing
28(1) If the legal owner of a generating unit must perform model revalidation testing on the generating
unit as referenced in subsections 24(6), (7)and (8) then the legal owner must revalidate the parameters
of the models for the automatic voltage regulator, power system stabilizer and turbine-governor
system in accordance with the testing described in this subsection 28.
(2)
(3)
The legal owner must perform revalidation of the models for the automatic voltage regulator:
(a)
by testing in accordance with subsection 26; or
(b)
by analysis of a disturbance that results in a sudden change in the reactive power output
from the generating unit greater than ten percent (10%) of rated MVA;
The legal owner must perform revalidation of the models for the turbine-governor system:
(a)
by testing in accordance with subsection 26; or
(b)
by analysis of a disturbance that results in a sudden change of the transmission system
frequency greater than zero point zero five (0.05) Hz.
Appendices
Appendix 1 - Reactive Power–Voltage Ride Through Requirements for aExisting Generating Unit without
a Power Purchase ArrangementUnits
Appendix 2 – Reactive Power Requirements for a Generating Unit with a Power Purchase Arrangement
Appendix 3 – Voltage Ride-Through Requirements for New Generating Units
Appendix 43 – Frequency Ranges
Revision History
Effective
yyyy/-mm/-dd
Description
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Section 502.5 Generating Unit Technical
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Appendix 1
Reactive Power Requirements for a
Generating Unit without a Power Purchase Arrangement
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Section 502.5 Generating Unit Technical
Requirements
1.000
0.900
over excitation limiter
0.800
minimum
gross real power
(varies with unit)
0.700
0.600
0.90 power factor
0.500
reactive power requirements
Supply
0.400
0.300
Reactive Power (p.u.)
0.200
0.100
0.000
0.00
-0.100
Real Pow er (p.u.)
0.20
0.40
0.60
0.80
1.00
1.20
Absorb
-0.200
-0.300
-0.400
0.95 power factor
maximum
authorized
real power
-0.500
-0.600
under excitation limiter
-0.700
-0.800
-0.900
-1.000
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Section 502.5 Generating Unit Technical
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Appendix 2
Reactive Power Requirements
for a Generating Unit with a Power Purchase Arrangement
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Section 502.5 Generating Unit Technical
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1.000
0.900
over excitation limiter
0.800
minimum
gross real power
(varies with unit)
0.700
0.600
0.90 power factor
Reactive Power (p.u.)
Supply
0.500
reactive power requirements
during emergency or abnormal
0.400
0.300
0.200
reactive power requirements
during normal conditions (varies with
Power Purchase Arrangemnt)
0.100
0.000
0.00
-0.100
0.20
0.40
0.60
0.80
Real Power (p.u.)
1.00
1.20
Absorb
-0.200
-0.300
-0.400
0.95 power factor
-0.500
-0.600
under excitation limiter
maximum
authorized
real power
-0.700
-0.800
-0.900
-1.000
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Section 502.5 Generating Unit Technical
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Appendix 3
Voltage Ride -Through Requirements for
New Existing Generating Units
Overvoltage (Percentpercent)
Undervoltage (percent)
Time
110 %
90 %
N/A (continuous operating range)
-
80.0 %
40 Cycles
-
15.0 %
4 to 9 Cycles
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Section 502.5 Generating Unit Technical
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120%
110%
Voltage at Point of Connection (Percent)
100%
90%
Post Transient
Voltage Deviation
40 cycles @ 80%
80%
70%
60%
50%
40%
30%
20%
10%
Transient
Voltage
Deviation
4 to 9 cycles
(Normal
Clearing Time)
0%
-1.0
-0.5
Transient
Voltage No Trip
Zone
625 milliseconds
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
4.5
5.0
Tim e (seconds)
Issued for Stakeholder Consultation: 2011-12-06
Issued for Stakeholder Consultation: 2012-11-29
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ISO Rules
Part 500 Facilities
Division 502 Technical Requirements
Section 502.5 Generating Unit Technical
Requirements
Appendix 2
Voltage Ride-Through Requirements for New Generating Units
Overvoltage (percent)
Undervoltage (percent)
Time
110 %
90 %
N/A (continuous operating range)
-
75 %
3.0 seconds
-
65 %
2.0 seconds
115 %
-
1.0 seconds
117.5 %
-
0.5 seconds
-
45 %
0.3 seconds
120 %
-
0.2 seconds
-
0.0 %
4 to 9 Cycles
Issued for Stakeholder Consultation: 2011-12-06
Issued for Stakeholder Consultation: 2012-11-29
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ISO Rules
Part 500 Facilities
Division 502 Technical Requirements
Section 502.5 Generating Unit Technical
Requirements
130%
0.2 seconds @ 120%
0.5 seconds @ 117.5%
1.0 seconds @ 115%
120%
110%
Voltage at Point of Connection (Percent)
100%
90%
80%
3.0 seconds
@ 75%
70%
2.0 seconds
@ 65%
60%
50%
0.3 seconds
@ 45%
40%
30%
20%
10%
4 to 9 cycles (Normal
Clearing Time) @ 0.0%
0%
-1.0
-0.5
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
4.5
5.0
Time (seconds)
Issued for Stakeholder Consultation: 2011-12-06
Issued for Stakeholder Consultation: 2012-11-29
Page 1 of 20
Page 32 of 36
ISO Rules
Part 500 Facilities
Division 502 Technical Requirements
Section 502.5 Generating Unit Technical
Requirements
130%
0.2 seconds @ 120%
0.5 seconds @ 117.5%
1.0 seconds @ 115%
120%
110%
Voltage at Point of Connection (Percent)
100%
90%
80%
3.0 seconds
@ 75%
70%
2.0 seconds
@ 65%
60%
50%
0.3 seconds
@ 45%
40%
30%
20%
10%
4 to 9 cycles (Normal
Clearing Time) @ 0.0%
0%
-1.0
-0.5
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
4.5
5.0
Time (seconds)
Issued for Stakeholder Consultation: 2011-12-06
Issued for Stakeholder Consultation: 2012-11-29
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ISO Rules
Part 500 Facilities
Division 502 Technical Requirements
Section 502.5 Generating Unit Technical
Requirements
Appendix 43
Frequency Ranges
Under-Frequency Limit (Hz)
Over-Frequency Limit (Hz)
Minimum Time
> 59.4 Hz
60.0 Hz to < 60.6 Hz
N/A (continuous operating range)
≤ 59.4 Hz
≥60.6 Hz
3 minutes
≤ 58.4 Hz
≥61.6 Hz
30 seconds
≤ 57.8 Hz
7.5 seconds
≤ 57.3 Hz
45 cycles
≤ 57.0 Hz
≥61.7 Hz
Issued for Stakeholder Consultation: 2011-12-06
Issued for Stakeholder Consultation: 2012-11-29
instantaneous trip
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Page 34 of 36
ISO Rules
Part 500 Facilities
Division 502 Technical Requirements
Section 502.5 Generating Unit Technical
Requirements
62.5
Instantaneous tripping is
permited at 61.7 Hz and above.
< 61.7 and > 61.6 Hz @ 30 s
62
61.5
< 61.6 and > 60.6 Hz @ 180 s
61
60.5
Frequency (Hertz)
60
> 59.4and < 61.6Hz = continuous operation
59.5
59
> 58.4 and < 59.4 Hz @ 180 s
58.5
> 57.8 and < 58.4 Hz @ 30 s
58
> 57.3 and < 57.8 Hz @ 7.5 s
57.5
> 57 and < 57.3 Hz @ 0.75 s
57
Instantaneous tripping is
permitted at 57.0 Hz and below.
56.5
56
-50
0
50
100
150
200
250
300
Time (seconds)
Under Frequency Requirement
Issued for Stakeholder Consultation: 2011-12-06
Issued for Stakeholder Consultation: 2012-11-29
Over Frequency Requirement
Page 1 of 20
Page 35 of 36
ISO Rules
Part 500 Facilities
Division 502 Technical Requirements
Section 502.5 Generating Unit Technical
Requirements
62.5
Instantaneous tripping is
permited at 61.7 Hz and above.
< 61.7 and > 61.6 Hz @ 30 s
62
61.5
< 61.6 and > 60.6 Hz @ 180 s
61
60.5
Frequency (Hertz)
60
> 59.4and < 61.6Hz = continuous operation
59.5
59
> 58.4 and < 59.4 Hz @ 180 s
58.5
> 57.8 and < 58.4 Hz @ 30 s
58
> 57.3 and < 57.8 Hz @ 7.5 s
57.5
> 57 and < 57.3 Hz @ 0.75 s
57
Instantaneous tripping is
permitted at 57.0 Hz and below.
56.5
56
-50
0
50
100
150
200
250
300
Time (seconds)
Under Frequency Requirement
Issued for Stakeholder Consultation: 2011-12-06
Issued for Stakeholder Consultation: 2012-11-29
Over Frequency Requirement
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