Download 515 SOUTH AREA OPERATION

Operating Policies and Procedures
Transmission
OPP 515
Effective: 2010-10-28
Filed with Commission: XXXX
Supersedes 2009-12-15YYYYY
515 SOUTH AREA OPERATION
Internal Consultation Draft 12.0
February 17, 2011
1.
Purpose
These operating policiesISO rules set out the requirements for:
(a) the ISO and procedures describe how to manage and reliably operate the transmission
system,certain market participants, and specifically the legal owners and
operators of any wind aggregated generating facilities and any other, generating
units or transmission facilities, to reliably manage and operate the South
Alberta area of the interconnected electric system during a period of constraint
in the souththat area of Alberta.; and
(b) the ISO to implement certain wind power management provisions allowing the ISO
to calculate a real power limit and allocate it to any wind aggregated generating
facility in the South Alberta area, when the interconnected electric system
cannot absorb the total real power increase due to the ramping of all wind
aggregated generating facilities operating in Alberta.
2.
Background
(1) The SW 240kV upgrade in the south area ofSouth Alberta area removes some of the
operational complexities in that area. Remedial action schemes continue to be required
to trip a connecting breaker or run-back or trip generation MW output in response to adverse
operating or transmissioninterconnected electric system constraint conditions.
(2) The 893L remedial action scheme monitors and prevents overloads on 893L
affecting the output from Summerview #2. The remaining remedial action schemes in
these operating policies and proceduresISO rules reduce bulk transmission line overloads to
ensure that load is served in the Pincher Creek area and to support the 69kV
transmission system in the south area ofSouth Alberta. Other remedial area. Remedial
action schemes in for the Lethbridge area in other ISO rules provide additional protection
to the 69kV transmission system in the south area ofSouth Alberta area.
(3) If a remedial action scheme is not triggered or is rendered partially or completely
inoperable, then the ISO must intervene to remove overloads on transmission system
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facilities and, in general, to maintain the reliability and integritysafety of the
transmissioninterconnected electric system in the south area ofSouth Alberta area.
(4) The southSouth Alberta area wind aggregated generating facilities and generating
units are illustrated in Figure 1 and Figure 2. A list of wind aggregated generating facilities in the
south area is provided in Table 1 . and Table 2 and Table 3 list the remedial action
schemes and the affected wind aggregated generating facilities associated with each
remedial action schemes for the south area of Alberta. For clarity, Figure 1 and Table 2 are in
effect as of the effective date of this section of the ISO rules, except that when Fidler and Castle Rock
Ridge have been commissioned, Figure 2 and Table 3 will be in effect and supersede Figure 1 and
Table 2. For more information on these facilities, see Appendix A.South Alberta area.
3H
4H
5H
7H
8H
10H
6H
9H
1H
(5) The ISO must manage the rapid increases in the total amount of real power
generated from wind aggregated generating facilities in Alberta that cannot otherwise
be managed under other ISO rules such as those pertaining to energy market merit
order procedures.
(6) These ISO rules therefore are intended to temporarily limit the ramp rates and real
power output of any wind aggregated generating facility operating in the South Alberta
area, until the ISO determines that the interconnected electric system can
accommodate the total amount of real power generated from all wind aggregated
generating facilities in Alberta.
3.
3B
Policy
(3.1) Transmission System Constraints
(1) The ISO must mitigate transmission system overloads caused by a single
contingency by curtailing real power generation MW output through the operation of
remedial action schemes or by issuing directives, or by both means as applicable to the
particular situation.
(2) The operator of any wind aggregated generating facility must notify the ISO
before the operator closes a breaker at the applicable point of connection, energizes
the collector bus feeder after an outage, or increases generation output after being
tripped or runback.
(3) If there is a loss of any component or all of a remedial action scheme, the ISO must
carry out a real-time assessment and must develop and implement a mitigation plan to
effectively mitigate the loss.
(4) All Subject to subsection 3.1(5), all wind aggregated generating facilities in the
South Alberta area and generating units must, within ten (10) minutes of being issued a directive,
curtail generation MW output to the MW level specified in a directive and must not exceed that MW
level for the period of time that the directive is in effect.
(5) With the exception of Cowley Ridge, Castle River, Taylor Chute, and McBride Lake, any wind
aggregated generating facility must comply with a directive within ten (10) minutes or, failing
compliance within ten (10) minutes, must notify the ISO and provide an explanation and an estimate of
the time required to comply with the directive.
(6) The specific remedial action scheme characteristics for Peigan 59S616LW are as follows:
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(a) the Peigan 59S616LW remedial action scheme for monitoring 616L (Goose Lake 103S Peigan 59S) is based on the dynamic thermal line rating for initiating generation MW output
runback signals when 616L exceeds 100% of the dynamic thermal line rating calculated rating for
ten (10) seconds;
(b) the maximum continuous rating generated from the dynamic thermal line rating will be limited to
600 A (143 MVA at rated voltage) in the summer and 720 A (172 MVA at rated voltage) in the winter
due to thermal constraints on terminal equipment; reliability directives.
(c) the remedial action scheme will initiate instantaneous(5) Subsection 3.1(4) does not apply to
the following wind aggregated generating facilities tripping signals for line loading ≥ 110% of
dynamic thermal line rating calculated ratings for ten (10) seconds; and , as represented by their
asset descriptions: Castle River, Cowley Ridge, McBride Lake, and Taylor Chute.
(d) upon loss of the dynamic thermal line rating, the remedial action scheme will use static
seasonal thermal line rating.
(7) The 786L Coleman remedial action scheme will operate for overload conditions on 786L at the
Coleman substation (T799S) and be triggered when static seasonal thermal line ratings are exceeded.
(8) (6) The ISO must issue a directive to the operator of an applicable transmission
facility to open the connecting breakers of any wind aggregated generation facility in
order to maintain reliability of the transmissioninterconnected electric system or to
protect transmissioninterconnected electric system facilities if generation MW output
cannot be curtailed within ten (10) minutes. The operator must not close the connecting
breakers again without approval from the ISO.
3.2 Wind Power Ramp Management
(1) This subsection 3.2 does not apply to the following wind aggregated generating
facilities, as represented by their asset descriptions: Castle River #1, Cowley Ridge,
Kettles Hill, Magrath, McBride Lake, Summerview #1 and Taylor Chute.
(2) Prior to issuing any directive curtailing real power output from any wind
aggregated generating facility in the South Alberta area, the ISO first must use the
energy market merit order procedures for energy balance to manage the ramping up of
the total real power output from all wind aggregated generating facilities in Alberta.
(3) If the energy market merit order procedures are insufficient to manage the
ramping up and the associated real power output from all wind aggregated generating
facilities, then the ISO must limit the total real power output for all of those wind
aggregated generating facilities, and in accordance with this subsection 3.2 specify a
wind power limit pro rata share for each wind aggregated generating facility in the South
Alberta area.
(4) The ISO must calculate, at a minimum interval of every twenty (20) minutes, the
system wind power limit by using the total real power output limit from all wind
aggregated generating facilities in Alberta.
(5) The system wind power limit in MW for an interval will be the greater of (a) and (b),
calculated as follows:
(a) (i) the total real power output from all wind aggregated generating facilities
referred to in subsection 3.2(4);
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plus
(ii) the ISO estimates in MW of:
(A)
the ramp rate-down capability in MW per minute, of all assets in the
energy market merit order for the interval;
plus
(B)
increases or decrease in the Alberta internal load for the interval;
plus
(C)
increases or decreases in any interchange schedule quantities for the
interval;
(b) (i) the total real power output from all wind aggregated generating facilities
referred to in subsection 3.2(4);
plus
(ii) six point five (6.5) MW per minute for the interval.
(6) Prior to the system wind power limit being exceeded by the total real power output
at any time during a settlement interval, the ISO must issue a directive to each
operator of a wind aggregated generating facility in the South Alberta area, specifying
the wind power limit pro rata share for that wind aggregated generating facility.
(7) The wind power limit pro rata share for each wind aggregated generating facility in
the South Alberta area is equal to:
(a) the potential real power capability of the wind aggregated generating facility as
filed with the ISO by the legal owner;
divided by
(b) the sum of the potential real power capabilities of all wind aggregated
generating facilities in Alberta as required to be filed by the legal owners under the
ISO rules;
multiplied by
(c) the system wind power limit.
(8) The operator of any wind aggregated generating facility must comply with a wind
power limit pro rata share directive no later than ten (10) minutes after the ISO has sent it,
and no wind aggregated generating facility may generate an amount of real power
output in excess of the wind power limit pro rata share specified in that directive while it is
in effect.
(9) The ISO must cancel all wind power limit pro rata share directives when the system
wind power limit no longer is exceeded.
(10) If at any one time any wind aggregated generating facility is constrained in real
power output by multiple concurrent directives from the ISO, including those for a local
transmission constraint, or the determination of a wind power limit pro rata share
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requirement, then the operator must comply with the lowest output limit of all limits
specified in the directives.
(11) If the ISO issues a directive to the operator of any wind aggregated generating
facility that results in a net increase in the real power input, then the ramp rate in MWs
per minute must not exceed ten percent (10%) of maximum authorized real power.
4.
Responsibilities
4.1
ISO
(1) If If under subsection 3.1 the ISO cannot determine that the risk to the
transmissioninterconnected electric system is low from a complete or partial component
loss of a remedial action scheme, then the ISO must:
(a) manually implement the mitigating actions of the remedial action scheme if any
automatic remedial action scheme functionality is unavailable, and issue
directives effecting curtailments as required to maintain reliability; or
(b) issue a directive curtailing specific wind aggregated generating facilities to zero
(0) MW until the constraint problem is resolved or the wind aggregated facilities
are again a functioning part of the remedial action scheme.
(2)
For voltage or reliability issues, the ISO must:
(a) with the exception of Cowley Ridge, Castle River, Taylor Chute and McBride Lake,subject to
subsection 3.1(5), issue voltage directives to the operators of wind aggregated
generating facilities and generating units to operate their voltage
regulationregulating systems as required; and
(b) issue directives to the operators of wind aggregated generating facilities,
generating units and transmission facilities, as applicable,; to curtail generation
MW output or remove transmission facilities as required to maintain reliability.
(3) With regard to wind power management under subsection 3.2 the ISO must
calculate:
(a) the system wind power limit; and
(b) the wind power limit pro rata shares and issue related directives in accordance
with that subsection.
4.2
Operators of any Wind Aggregated Generating FacilitiesFacility and any
Generating Units
Unit Under Constraint Conditions
With regard to constraint conditions under subsection 3.1, each operator of a generating
unit or any wind aggregated generating facility must:
(1)
obtain approval from the ISO prior to:
(a) reconnecting the subject facilities to the transmission system under the circumstances set out
in this section of the ISO rulesto the interconnected electric system;
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(b) after a forced outage or planned outage, closing the collector bus breakers or
connection breakers to any feeder in the wind aggregated generating
facilitiesfacility collector bus system; or
(c) increasing generation MWreal power output after being tripped or runback due to
the operation of a remedial action scheme or after being curtailed by a directive;
(2) within ten (10) minutes of being issued a directive to curtail generation, curtail
generation MW output to the MW level identified in that directive;
(3) limit the generation MWreal power output to the level identified in that directive
during the time the directive is in effect;
(4) within ten (10) minutes of being issued a directive for voltage adjustments, comply
with that directive; and
(5) inform the ISO immediately if they are unable to comply with a directive within ten
(10) minutes of being issued the directive, and provide reasons and an estimated time
required to comply with the directive.
4.3
Legal Owner of a Transmission FacilitiesFacility Under Constraint Conditions
UnderWith regard to constraint conditions under subsection 3.1, the legal owner of a
transmission facility must:
(1) take immediate action to operate the transmission facility in a manner that protects
their equipment and personnel, the public, and the environment, and notify the ISO of
these actions as soon as possible;
(2) comply with any directive from the ISO to remove any real power generation MW
output by opening connection breakers or removing transmission facilities associated
with wind aggregated generating facilities, unless such action could result in damage to
transmission facilities, be hazardous to personnel, the public or the environment; and
(3) obtain approval from the ISO before closing the connection breakers of any wind
aggregated generating facilityfacilities.
5.
System Controller Procedures
5.1
Adjusting Voltages Using Wind Aggregated Generating Facilities and
generating units
To adjust the voltage at any wind aggregated generating facility or generating unit, the ISO must:
(1) issue a directive to any applicable operator as listed in Table 4 (confidential) with regard to
operating the voltage regulation system for that facility;
(2) coordinate operation of voltage regulating systems so that south area voltage support is
provided and VAr balance among appropriate wind aggregated generating facilities and
generating units is maintained.; and
(3) if informed by the operator of any wind aggregated generating facility or any generating unit
of the inability to comply with a directive:
(a) assess the south area requirements considering the estimated time that the operator
requires to make the voltage adjustment;
(b) take alternative action if required (including tripping of generation or load); and
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(c) record the date, time, description of the event, and the operator’s reason for the
operator’s inability to comply with the voltage adjustment directive in the ISO shift log.
5.2
786L Overload at 799S Coleman
(1) Overloading on 786L may occur under normal operation with high exports and low area load
or high wind aggregated generating facility output.
(2) The following are the methods that the ISO may employ to alleviate an overload on 786L:
(a) primary method: manually open the 786L breaker at Coleman (799S). Under normal
system conditions the ISO will verify 786L loading has reached 90% of the seasonal
thermal line rating and telephone the Altalink Control Center (ACC) to request that the
ACC open breaker 799S786W at Coleman when the line loading reaches 95%; and
(b) secondary method: automatically with the operation of the786L remedial action scheme.
(3) When the overload occurs rapidly and operator intervention is not possible, the 786L
remedial action scheme will operate. If the 786L remedial action scheme has operated, the ISO
will:
(a) telephone the ACC and request that it open the 799S786W breaker at Coleman; and
(b) allow any curtailed generating unit to resume full output when the 799S786W breaker is
open; or
(c) if the ACC declines to open the breaker, issue directives to curtail all effective generating
units on a pro-rated basis, based on the actual output at the time of the 786L remedial
action scheme operation.
(4) To restore the 786L breaker at 799S Coleman, the ISO will:
(a) as system conditions allow and when the ISO is confident that 786L will not overload,
request the ACC to close the 799S786LW breaker at Coleman; and
(b) record the date, time, and description of the event in the ISO shift log.
(5) The 786L remedial action scheme will:
(a) send a signal to runback generation for ten (10) minutes to the wind aggregated
generating facilities (see Table 2 or Table 3) if 786L loading reaches:
(i) 99 MVA in the summer for ten (10) seconds; or
(ii) 132 MVA in the winter for ten (10) seconds.
(b) trip generation at wind aggregated generating facilities (see Table 2 or Table 3) if it
reaches:
(i) 109 MVA in the summer for ten (10) seconds; or
(ii) 146 MVA in the winter for ten (10) seconds.
5.3
Post Remedial Action Scheme Operation
(1) After a remedial action scheme has operated in the south area, the ISO will:
(a) identify the remedial action scheme participants using Table 2 or Table 3; and
(b) issue directives to curtail all effective generating units and wind aggregated generating
facilities on a pro-rated basis, based on the actual output at the time of the remedial
action scheme operation.
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(2) For greater certainty, with regard to any directive to be issued under subsection (1), there will
be only one directive issued to each of:
(a) Summerview 1 and 2; and
(b) Ardenville and Blue Trail.
5.4 Loss of a 138kV path (164L, 863L or 820L) to the 69kV transmission system
(1) To mitigate the possibility of voltage collapse on the 69kV system (N-1-1 contingency) for
the loss of any one of the following 138kV paths:
(a) 164L Goose Lake (T103S) to Drywood (T415S);
(b) 863L path including; Magrath (T225S) 138/69 kV transformer or 863L Riverbend
(L618S) to Magrath or (725AL Bowron (L674S) to Riverbend (L674S) and 824L
Lakeview (L593S) to Riverbend (L618S));
(c) 820L Coaldale (T254S) to Sterling (T67S);
the ISO must prepare the 69 kV system for the next contingency by notifying the real time
manager of the situation and either:
(a) running a study in real time to determine mitigation steps; or
(b) requesting the Operations Coordination group to determine mitigation steps.
5.
Revision History
Issued
Description
2011-xx-xx
Supersedes 2010-10-13
2010-10-13
Supersedes 2009-12-15
2009-12-15
Supersedes 2009-09-04
2009-09-04
Supersedes 2008-07-28
2008-07-28
Supersedes 2007-09-27
2007-09-27
Supersedes 2007-06-14
2007-06-14
Supersedes 2007-03-15
2007-03-15
Supersedes 2006-09-29
2006-09-29
Supersedes interim OPP effective 2006-08-09
2006-08-09
Approved for interim implementation, supersedes 2006-04-27
2006-04-27
Supersedes revised interim OPP effective 2005-07-27
2005-07-27
Supersedes revised interim OPP effective 2005-06-14
2005-06-14
Supersedes interim OPP effective 2005-06-03
2005-06-03
Supersedes OPP effective 2004-10-14
2004-10-14
Supersedes interim OPP effective 2004-07-30
2004-07-30
Approved for interim implementation, effective 2004-07-30
New issue
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6.
Figures and Tables
Figure 1
South Alberta Area Wind Aggregated Generating Facilitiesgenerating facilities and Generating Unitsunits: Current
Configuration
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Figure 2
South Alberta Area Wind Aggregated Generating Facilitiesgenerating facilities and Generating Unitsunits: Castle
Rock/Fidler Extension
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Table 1
South Area Wind Aggregated Generating Facilities and Generating Units
Remedial action schemes In Effect in the South Alberta area
Operator
GeneratorSouth Area RAS
Ardenville
Substation
TransAlta
418S
69
Castle Rock
Ridge Corp.
205S
115
Blue Trail
TransAlta
528S
66
Summerview #2
TransAlta
354S
66
Old Man 2 Wind
Farm Ltd.
112S
46
Soderglen
TransAlta
243S
70.5
Kettles Hill
ENMAX
383S
63
TransAlta
354S
68.4
ENMAX
C134S
80
Suncor
139S
30
30
Castle Rock
Ridge
Old Man River
Wind
Summerview #1
ENMAX Taber
Suncor Chin
Chute
(Hillridge
substation)
Magrath
Suncor
226S
Irrican Hydro
Irrigation Canal
Power
Cooperative Ltd.
67S
(25 kV)
McBride Lake
TransAlta
240S
75.2
Taylor (wind)
TransAlta
Taylor
3.4
Raymond
Reservoir
Irrigation Canal
Power
Cooperative Ltd.
T313S
18
Chin Chute
Hydro
Irrigation Canal
Power
Cooperative Ltd.
T315S
11
ATCO
A806S
32
Drywood Power
Plant
Bow Ark
T415S
6
Taylor Chute
Hydro
TransAlta
Taylor Hydro
12
Cowley Ridge
TransAlta
322S
40.775
Castle River
TransAlta
239S
39.54
Belly River
Chute
TransAlta
229S
2.9
St. Mary’s Hydro
TransAlta
385S (25 kV)
2.4
Waterton Hydro
TransAlta
415S (25kV)
2.5
Old Man River
Hydro
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Capability
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Table 2
Remedial Action Schemes In Effect in south Alberta
South Area RAS
#
RAS Monitoring Point
Affected Generation
1
At Coleman 786L (T799S – BCTC Natal)
Summerview #2, Summerview #1, Blue Trail, Ardenville,
Kettles Hill, and Soderglen
2
At Goose Lake 103S 893L (T103S)
Summerview #2,
3
At Goose Lake T103S 616L Terminal
Ardenville, Blue Trail, Soderglen
4
At Peigan 59S 616L Terminal
Summerview #2, Kettles Hill, Summerview #1
5
At Peigan T59s transformer T1
Ardenville, Blue Trail, Summerview #2,
6
At Spring Coulee 225L West, (385S – 229S)
None. Trips 385S225W to remove the overload
7
At Magrath or Riverbend 863L or
Magrath Garden City
8
Loss of the Magrath 225S transformer T1
Magrath Garden CityTaylor Chute, Taylor Hydro
Table 32
Remedial Action Schemesaction schemes Remaining in Effect in southSouth Alberta area
after removal of 893L
South Area RAS
#
RAS Monitoring Point
Affected Generation
1
At Coleman 786L (T799S – BCTC Natal)
Castle Rock Ridge, Summerview #2, Summerview #1, Old
Man River Wind, Blue Trail, Ardenville, Kettles Hill, and
Soderglen
2
At Goose Lake T103S 616L Terminal
Ardenville, Blue Trail, Soderglen
3
At Peigan 59S 616L Terminal
Castle Rock Ridge, Summerview #2, Old Man River Wind,
Kettles Hill, Summerview #1
4
At Peigan T59s transformer T1
Ardenville, Blue Trail, Castle Rock Ridge, Summerview #2,
Old Man River Wind
5
At Spring Coulee 225L West, (385S – 229S)
None. Trip 385S225W to remove the overload
6
At Magrath or Riverbend 863L or
Magrath Garden City
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South Area RAS
7
Loss of the Magrath 225S transformer T1
Magrath Garden CityTaylor Chute, Taylor Hydro
Table 4
Contact Information
The contents of this Table 4 are confidential.
7.
Revision History
Issued
Description
2010-xx-xx
Supersedes 2009-12-15
2009-12-15
Supersedes 2009-09-04
2009-09-04
Supersedes 2008-07-28
2008-07-28
Supersedes 2007-09-27
2007-09-27
Supersedes 2007-06-14
2007-06-14
Supersedes 2007-03-15
2007-03-15
Supersedes 2006-09-29
2006-09-29
Supersedes interim OPP effective 2006-08-09
2006-08-09
Approved for interim implementation, supersedes 2006-04-27
2006-04-27
Supersedes revised interim OPP effective 2005-07-27
2005-07-27
Supersedes revised interim OPP effective 2005-06-14
2005-06-14
Supersedes interim OPP effective 2005-06-03
2005-06-03
Supersedes OPP effective 2004-10-14
2004-10-14
Supersedes interim OPP effective 2004-07-30
2004-07-30
Approved for interim implementation, effective 2004-07-30
New issue
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Appendix A. Information on South Area Wind Aggregated Generating
Facilities and Generating Units
(1) The wind turbine generators at the Magrath wind aggregated generating facility, Garden City (226S), are
doubly-fed induction machines capable of controlling reactive power. A WindVar device has been installed at
the Garden City substation (226S). It will send a command signal to all the wind turbine generators to adjust
reactive power in order to regulate the collector bus substation voltage. The Magrath wind aggregated
generating facility will operate to a voltage control set point. Garden City (226S) is connected via 891L/863L
between Riverbend (T618S) and Magrath (T225S). This line is protected by a line overcurrent differential
scheme.
(2) Six 6.6 MVAr independently switched capacitor banks and an 8 MVAr Dynamic VAR (D-VAR) voltage
regulation system have been installed at the Summerview substation (354S) for voltage control. The D-VAR
operates to a voltage control set point. The Old Man River Hydro (A806S) generation is connected to the
Goose Lake substation (T103S) on the same line as Summerview wind aggregated generating facility via 893L.
This line is protected by a line overcurrent differential scheme.
(3) 354S connects Summerview #2 to the transmission system. It has one 10 MVAr capacitor and two 4
MVAr D-VAR voltage regulating systems for voltage control.
(4) The wind turbine generators at the Taylor wind aggregated generating facility are induction machines with
back-to-back rectifier-inverter units providing power factor control. The Taylor wind aggregated generating
facility is located adjacent to the Taylor Hydro generating unit which is radially connected to Magrath
(T225S). No voltage control devices are located at the site.
(5) The Kettles Hill wind aggregated generating facility is located approximately 7 km from the Goose Lake
substation (T103S) and 24 km from Peigan substation (59S). The associated Kettles Hill substation (383S) is
T-tapped from 616L. This wind aggregated generating facility is comprised of 35 sets of 1.8 MW
asynchronous generating units, totalling 63 MW. The voltage regulation system consists of five 6.6 MVAr
independently switched capacitor banks and an 8 MVAr D-VAR.
(6) The Soderglen wind aggregated generating facility is comprised of 47 sets of 1.5 MW asynchronous
generating units, totalling 70.5 MW. The wind turbine generators are equipped with wind volt-amp-reactive
(WindVAR) system for voltage regulation. The associated Soderglen substation (243S) is on a radial feed from
59S Peigan.
(7) The Suncor Chin Chute wind aggregated generating facility is comprised of 20 sets of 1.5 MW doubly-fed
asynchronous generating units, totalling 30 MW. The associated Hillridge substation (139S) is T-tapped from
172L (Coaldale T254S – Taber T83S). This wind aggregated generating facility is equipped with a dynamic
voltage regulator together with an 8 MVAr capacitor bank for voltage control.
(8) The ENMAX Taber wind aggregated generating facility is comprised of 37 sets of 2.2 MW wind turbine
generators, totalling 81.4 MW. The associated Taber Wind substation (C134S) is T-tapped from 607L
(Fincastle T336S – Conrad T135S). The reactive power system is comprised of a 4.2 MVAr capacitor bank on
each of the two collector busses and dynamic VAR capability from the wind turbine generators.
(9) The Blue Trail wind aggregated generating facility is comprised of 22 sets of 3 MW wind turbine
generators. The associated Blue Trail substation (528S) is connected to the Peigan substation (59S) by 608L.
The voltage regulation system consists of 2 sets of 8.2 MVAr capacitor banks and a 10 MVAr D-VAR.
(10) Ardenville wind aggregated generating facility is comprised of 23 sets of 3 MW wind turbine generators
totalling 69 MW. The associated Ardenville substation (418S) is T-tapped from 608L (Peigan 59S – Blue Trail
528S). The Ardenville voltage system consists of 3 – 6.6MVAr capacitors and one 8 MVAr D-VAR.
Issued for Stakeholder Consultation: 2011-02-17
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Transmission
OPP 515 South Area Operation
(11) Old Man River Wind aggregated generating facility is comprised of 20 wind turbine generators rated at
2.3 MW each totalling 46 MW. Voltage control at the site comprises of a static VAR compensator (SVC) and
two shunt capacitors.
(12) Castle Rock Ridge wind aggregated generating facility has a generating capacity of 116 MW and will
consist of fifty eight (58) 2.0 MW wind turbine generators. It is located approximately 4.5 km north and 4 km
west of the Goose Lake substation.
Issued for Stakeholder Consultation: 2011-02-17
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