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Techno-Economic Evaluation of Power Factor
Improvement Scheme for 11kV, 40kA, 72MW
Main Bulk Intake Substation
Yadavalli Venkata Sridhar and Fakher Al Zalzalah Kuwait Oil Company, Ahmadi, Kuwait
Email: {ysridhar, fzalzala }@kockw.com
Abstract—Techno – Economic Evaluation of power factor
improvement scheme for 11kV, 40kA, 72 MW main bulk
intake substation related electrical network that feeds
various far flung located facility substations consisting of
drive motors that operate in VFD mode & bypass mode.
Evaluation takes into consideration, load profile assessment
for maximum & minimum variation of electrical loads due
to through put capacity variation of facilities and facility
shutdowns for turnarounds. Evaluation covers ETAP
modeling, measurement of harmonic pollution at facility
substations and makes a selection of technology based on
market survey, and addresses the possible alternatives
pertaining to the location of PF improvement equipment in
the network and concludes with cost effectiveness of the
recommended solution. Advantages and disadvantages of
various models discussed.
Index Terms—power factor, Variable Speed Drive (VSD),
harmonics, cost
I. INTRODUCTION
Main Bulk in Take (MBIT) substation is rated for 72MW and feeds to Unit-1, Unit-2, Unit-3, Unit-4, Unit-5, Unit-6, Office complex and Workshop Facilities. If all these facilities operate at their full load capacity the power flow from Main Bulk Intake substation is expected to be in the range of 33MW.
The above stated existing facilities are expected to be further expanded in the various projects to the extent of approximately 10 MW. Further, 25MW is allocated for ongoing project Nos. 13 and 60.
Refer to the Figure. 1 for existing single line diagram
of MBIT substation.
Figure 1.
Manuscript received November 1, 2012; revised December 29,
2012.
A. Power Factor at 0.95 or Above at Main Bulk Intake
Substation
Power Factor is required to be maintained 0.95 or
above at the main bulk in take substation to meet the local
legislation requirements irrespective of type & nature of
load, variations in the load due to less through put &
shutdown activity of the facilities, harmonics presence
and expansion of facilities.
B. Type and Nature of the Connected Load
All units have non liner loads (Variable Speed Drives-
VSDs) that may operate in VSD mode or by pass mode.
The rating of the VSD drive motors is in the range of
1MW and 2.9 MW.
The loads of project nos. 13 & 60 will also be installed
with three (3) Variable Speed Drives each of size 7.1MW.
The other load composition consists of induction
motors of various sizes connected to 3.3kV and 440 volt
level along with associated transformers. Lighting loads
and small nonlinear loads such as battery chargers, UPS
systems, Computers and Switch Mode Power Supplies
(SMPS) are connected at the 440 volts level.
C. Presence of Harmonics and Harmonic Related
Information
As the nonlinear loads operate at all the voltage levels
of existing electrical network, the following assumptions
are made:
The main contribution of harmonics is expected to be
from Variable speed drives of Process Unit drivers.
Hence the physical harmonic measurements carried out at
the 11kV buses of units.
The capacity of UPS systems & Battery Charger(s) is
much less than 15% of the corresponding transformer
capacity at the 440 voltage level; hence the harmonic
presence is ignored.
Refer to Table 1 for existing Harmonics measurements
carried out at the 11KV level of each facility where such
Variable Speed Drivers are operating.
D. Maximum and Minimum Variations of Load and
Load Profile of MBIT Substation
An assessment is carried out for the load variation and
load profile of the MBIT substation. The following
loading conditions are identified:
International Journal of Electrical Energy, Vol.1, No.1, March 2013
37©2013 Engineering and Technology Publishing doi: 10.12720/ijoee.1.1.37-42
For maximum loading conditions, Unit 1, Unit-2,
Unit-3, Unit-4, Unit-5 and Unit-6 are operated
simultaneously to meet the production needs.
For minimum loading conditions, facilities Unit
-1, Unit-2, Unit-3,Unit-4, Unit-5 and Unit-6 are
operated in any of the following combinations:
may operate at reduced percentages of
their full capacities
may be under shutdown
operation of VSDs in the bypass mode
operating standby facilities such as
existing gas engine/turbine facilities in
lieu of electrical drives.
Power requirement of Workshop and Office
Complex may vary during the week days and
weekends as the activity levels keeps on varying.
Ambient temperature imposed load variations
(Summer and Winter variations in HVAC loads
and operating loads)
In all the above conditions the power drawn from
MBIT substation will vary consequently the power factor
also will vary in wide range. Moreover, abnormal
operating conditions of process facilities (such as process
trips both partially and totally) will also impose variations
in the power drawn from MBIT substation.
TABLE I.
Unit Maximum voltage
distortion
Maximum current
distortion
Before
VSD
operatio
n %TH
D
After VSD
operation
%THD
Before
VSD
operation
%THD
After VSD
operation%
THD
Unit 1 1.22% 2.81% 1.62% 2.49%
Unit 2 0.0% 1.1% 1.03% 1.98%
Unit 3 1.27% 1.39% 1.22% 2.53%
Unit 4 1.9% Not
Available
6.3% Not
Available
Unit 5 0.0% 2.96% 0.0% 2.02%
For the purpose of power factor study of MBIT
substation the following Maximum/ Minimum operating
conditions are considered:
Maximum Power condition:
Maximum power when all existing facilities are
operating : 33MW
Maximum power inclusive of future load
additions at the existing facilities: 40 MW
All existing VSD’s operate in VSD mode and
these VSD’ operate at high power factor.
(above 0.95 power factor)
Minimum Power condition:
Two of the VSD’s of existing Units might
operate in the BYPASS mode.
Any two facilities are under shutdown and all
other facilities are operating.
The future load of 25 MW (approximate) pertaining to
the projects 13 and 19, have VSD’s and these will be
operating at a very high power factor. Approximately less
than 3 MW auxiliary loads at the low voltage level
(including lighting) may operate depending on the
process needs.
E. Analysis of Data:
All VSD’s operate at very high power factor.
Operation of VSD’s at facilities will
improve the power factor at MBIT
substation.
The long cables between MBIT substation
and Operating Facilities contribute for
improved power factor due to capacitance
of cables. This also has the impact of high
voltage drop and high heat loss.
At MBIT substation, which is Point of
Common Coupling with Utility, in general
the power factor is in the range of 0.92 or
above, depending on the load factor of the
MBIT substation. If Gas turbines/ Gas
engines (stand by equipment for VSD’s) are
utilized the power factor is expected to go
very low (to the level of 0.83).
F. Assessment of Technologies and Applicability of
Technology
Broadly three methods of power factor improvement
methods are identified:
Capacitor banks (Conventional method of
compensating the power factor improvement)
Active filters [1] (New technology for harmonic
filtering and reactive power compensation)
Hybrid systems (Combined systems of Active
filter plus capacitor banks)
The use of Synchronous Condenser is not considered
in the evaluation due to the reasons, that the existing
electrical network does not use synchronous motors.
Based on the initial assessment of reactive power that
is required to be provided at MBIT substation and range
of harmonic presence, a preliminary conclusion was
arrived, that Capacitor banks (passive technology) will
suffice to carry out the required power factor
improvement.
International Journal of Electrical Energy, Vol.1, No.1, March 2013
38©2013 Engineering and Technology Publishing
Review of various industry experiences in connection
with use of capacitor banks is consistent with the above
assumption.
Capacitor banks method of power factor improvement
is well proven technology and it has cost advantage over
other latest technologies. This method has few
disadvantages like inrush current, possibility of switching
failures etc. However taking into the consideration the
technology versus costs involved the power factor
improvement with capacitor banks is preferred [2].
The Manufacturers (ABB, Siemens, Schneider, Eaton
etc.) were assessed for the product range and their
capabilities.
Although the cost of passive capacitors is low in
comparison to other options (Active & Hybrid systems)
at this juncture, as the technology progresses further, the
relative cost between passive capacitors & other systems
is likely to become narrow in near future.
It is technically possible to compensate VAR at
132KV level of MBIT however practically this is not a
suitable solution as one giant capacitor bank needs to be
installed and the step sizes would be extremely large and
would not follow the load profile of the system very well
and cost of such a system is very expensive as the
associated 132KV switchgear is also required.
G. Possible Methods for Power Factor Improvement
Power factor improvement can be carried out in many
ways, such as central compensation, group compensation
and individual load compensation etc.
In the present application individual compensation is
not a good solution due to the multiplicity of drives and
implications of installation of many low voltage level
capacitors. Installation of load end capacitors is not
possible due to hazardous area classification requirements.
Group compensation for two or three facilities put
together is also ruled out due to the reasons of shutdown
schedules of the facilities are not concurrent and do not
match.
VAR compensation at High voltage and/or low voltage
levels of the facilities and compensation at MBIT is
studied in depth for their technical and economic
feasibility in the evaluation.
H. Defining Objectives of VAR Compensation
It is essential to define the objectives of the VAR
compensation very clearly to arrive at a solution. VAR
Compensation objective could be one of the below or
combination:
For compliance to Utility undertaking stipulation
for maintaining the power factor
For improvement of voltage profile & improve
voltage regulation
To relieve the system capacity to meet the
additional load demand
To reduce system losses
To have the combined benefits of all above
Based on the objective, approach and method for VAR
compensation will vary. In the subject evaluation,
compliance to Utility undertaking stipulation to maintain
0.95 at the point of common coupling along with
shutdown requirements of the operating facilities and
transfer of more power on the existing long distance
cables is defined as the objective.
II. SOLUTION AND ETAP SYSTEM STUDIES
Keeping the above objective in focus, selection of
capacitor banks as the equipment for VAR compensation
of MBIT network, the optimum placement of capacitor
banks is carried out the with support of ETAP software.
All the below mentioned three (3) models were studied in
the ETAP software in the steady state mode. Multiple
ETAP runs were carried out in the load flow studies
mode to vary size and location of the capacitor banks for
obtaining near optimum solutions.
A. Identifying the Models
With a view to identify best possible solution (s) for
Power Factor Improvement, Three (3) number models
were developed and studied for technical and financial
comparison purposes [5].
Model No.1: Determine the size and install the Power
Factor improvement at MBIT substation 11 kV bus bar.
(This is in line with objective i. mentioned above)
Model No.2: Determine the size and install the Power
Factor Improvement at 11kV buses of Unit-1, Unit -2,
Unit-3, Unit-4, Unit-5 and also at MBIT substation (This
is also in line with objectives i. and ii. along with load
variations due to shutdown schedules).
Model No.3: Determine the size and install the Power
Factor Improvement systems at 3.3kV levels & 440 volts
levels of Unit-1, Unit-2, Unit-3, Unit-4, Unit-5, Unit-6,
Office Complex and Workshop. (This is in line with all
the combined objectives stated above)
B. Evaluation of Model No:1
In this model two capacitor banks (2 X 5,200KVAR)
are required to be installed at 11kV bus of MBIT
substation.
This model meets the Utility stipulation of maintaining
the power factor improvement at 0.95 for load of 40MW
(ie. existing load plus future load on MBIT substation).
This scheme of power factor improvement is of low cost,
approximately $1,050,000/- and cheapest of three models
and easy to install at MBIT substation 11kV bus due to
the following:
Two spare breakers need to be allotted for
feeding the Capacitor bank that are readily
available in the panel line up.
Existing Floor space can be used for installing
the Capacitor bank panels
Shut down of the facilities is not required.
Requires least time for implementation.
Makes available additional KVA at MBIT
substation for future use (4,181KVA)
However this model has following disadvantages:
Number of steps of switching will be wide and
broad. Because of wide step size there is a
possibility a load bank may not be able to follow
International Journal of Electrical Energy, Vol.1, No.1, March 2013
39©2013 Engineering and Technology Publishing
load variations. In order to follow the load
variations, if the number of steps is increased,
this might increase the foot print of the overall
equipment.
Load variations that would happen due to the
shutdown of units cannot be totally addressed by
the model.
Reassessment of existing HVAC capacity of the
substation is required. Additional air
conditioning equipment will be required.
In this method of power factor improvement scheme,
all downstream equipment and cables will be subjected to
reactive loading and heat losses will continue to be as
earlier. However there is no impact on the electrical
efficiency of the network and power factor will not be
maintained at 0.95 at the unit substations fed by MBIT.
A preliminary steady state short circuit analysis
indicates that existing 11KV switchboard rating of 40KA
board is sufficient. Further, critical transient analysis
study is needed for analyzing the out rush current into the
faulted bus conditions to assess the impact of peak
making current rating of the board with the installation of
capacitor bank.
C. Evaluation of Model No:2
Total of 6 capacitor banks rated for 11kV are
considered in this model. One (5000KVAR) capacitor
bank at MBIT substation and one capacitor bank each at
Unit-1, Unit-2, Unit-3, Unit-4 and Unit-5 (1250KVAR
each) are required to be installed. Total capacitors will
deliver into the network 11,250 KVAR.
This Model No: 2 meets the Utility stipulation of
maintaining the power factor at 0.95 for load of 40MW at
MBIT Substation and also at each of 11KV bus of Unit
substations. In this Model No.2 existing lengthy cables to
each unit will be relieved of reactive current thereby
reducing the voltage drop & heat losses enabling transfer
of more power (over and above the existing power
transfer) on the existing cables within the stipulated
voltage drop of Company standard in order to meet the
future load additions at each of the Units. This model
releases the capacity at MBIT substation and makes
available additional 3968 KVA approximately at MBIT
substation level. In some cases such as Unit-2, the voltage
will be improved in this model due to installation of
power factor improvement equipment at 11KV bus of
Unit-2.
This Model No: 2 require one feeder breaker at each of
the unit 11KV bus and require space at each unit
substation for installation of 11KV capacitor banks. The
cost of this Model No: 2 is expected to be in the range of
$ 1,680,000/- . The advantages of Model No: 2 are as
follows:
The 11KV buses at Unit’s also will be
maintained to close 0.95 power factor for a load
of 6 to 6.5MW approximately.
On the existing cables (linking MBIT & Unit
substations) more power can be transferred
maintaining the percentage voltage drop within
the relevant standards.
Makes available additional KVA at MBIT
substation for future use (3,968KVA)
As the VAR compensation is done at the unit
substation, this gives better power factor control
at MBIT to maintain 0.95.
The disadvantages of Model No: 2 are as follows:
Total Six (6) capacitor banks are required
Space requirement is more and floor space has
to be created.
Method 2 costs more in comparison to that of
Model no1 and 3.
Shutdown is required at each of the panel.
D. Model No.3 Evaluation Results
In this Model No: 3 capacitor banks at 3.3KV
(600KVAR, 1 no.) bus and 440 volt (300KVAR, 2 nos.)
bus are considered in at Unit-1, Unit-2, Unit-3, Unit-4,
Unit-5. Further capacitor banks are considered at 440 volt
buses of Unit-6 (200KVAR,1no.), Workshop and Office
Complex at 440V level (250KVAR,1no.) and one
capacitor bank at MBIT substation(3000KVAR) for any
major change in load profile and non-availability of
capacitor banks at downstream substation due to
capacitor failures. Total capacitors will deliver into the
network 11,750 KVAR.
This Model No: 3 meets the Utility stipulation of
maintaining the power factor at 0.95 for 40MW load. In
total, 22 capacitor banks are required in this model. This
scheme releases 5052 KVA at MBIT substation and
releases the capacity of 3.3 KV & 440 volts transformers,
cables etc. at each of installed location, thereby reducing
the heat losses leading to energy efficient network. As
such, availability of additional capacity from transformer
(s) is not useful as there are technical limitations at the
11KV network level.
This Model no: 3 requires feeder breaker at each
voltage bus of the Unit (3.3KV bus and 440 volts buses)
and requires space for capacitor bank installation at each
of the unit for installation and existing floor space. The
cost of this Model no: 3 is expected to be in the range of
$ 1,395,000/-.
The advantages of Model 3 are as follows:
This model complies with the basic principle of
VAR compensation which shall be carried to
closer to the load.
3.3KV & 440 volts buses at Units also will be
improved and maintained at 0.95 power factor.
On the existing cables more power can be
transferred maintaining the percentage voltage
drop with in the relevant standards.
Because of distributed capacitor banks at all
voltage levels, system overall heat dissipation
losses reduce leading to the energy efficient
network.
Makes available additional KVA at MBIT
substation for future use (5052 KVA)
Cost is less in comparison to Model No.2
The disadvantages of Model No: 3 are as follows:
Twenty two (22) capacitor banks are required in
comparison to Model no.1 and Model.no2.
Shutdown is required at each of the switchboard.
International Journal of Electrical Energy, Vol.1, No.1, March 2013
40©2013 Engineering and Technology Publishing
Additional capacity released from 3.3KV and
440 volts transformers is not useful as this
capacity is not sufficient to power up expansion
facilities due to limitation of feeders and
limitations of expansion of 3.3KV and 440 volts
switchboards. Furthermore Units are expanded
by taking 11KV input to a new a localized
distribution substation for the purpose of facility
expansion.
E. Verification of Above Information Through
Internationally Reputed Manufacturers
A request for budgetary quote was forwarded to
internationally reputed North American and European
manufactures with all the relevant & complete data along
with defined objective. The approach adopted by the
reputed manufacturers also matched with the above
analysis. The budgetary quotes prices vary from each
other in a very wide range. The cost figures mentioned
above is based on budgetary costs taking other associated
costs.
Table 2 is brief cost comparison chart for the three
models in terms US dollars ($):
TABLE II.
S.No.
Description of Item
Model No.1
Model No.2
Model No.3
1 Capacitor
cost 517,500/-
1,084,173/-
690,000/-
2 Cabling works
22,500/- 29,400/- 30,000/-
3 Additional
feeder panels 150,000/- 150,000/- 255,000/-
4 Civil&HVAC
Works 300,000/- 300,000/- 150,000/-
5 Installation
cost 60,000/- 116,427/- 270,000/-
6 Total Cost 1,050,000/
- 1,680,000/
- 1,395,000/
-
F. Impact of Harmonics Present in the Existing
Network of MBIT Substation on the Proposed
Capacitor Banks:
The Budgetary quotes have taken into consideration
the harmonics present in the network and accordingly
each of the capacitor banks is provided with detuned
reactors. The detuned reactor in the capacitor bank circuit
ensures that resonance conditions are avoided,
consequently the harmonic currents will not flow through
the Capacitor Banks. The detuned capacitors also ensure
to limit the inrush currents to help improve the switching
transients. 7% detuning reactors will be part of capacitor
banks. The 7 % detuning reactor detunes the bank at
189Hz (below 4th
harmonic and above the 3rd
harmonic).
As the Capacitor banks with detuned reactors are meant
for power factor improvement only and do not perform
any harmonic filtering function. Hence with the capacitor
bank installation the harmonic pollution levels will not
change [3] and [6].
G. Capacitor Switching and Related Aspects
The capacitor switching operation (energizing, de-
energizing, fault clearing and reclosing etc.) is associated
with the following technical issues [2]:
Restrike due to excessive voltage across the
circuit breaker blades
Energize capacitor bank when another capacitor
bank is charged (known as back to back
switching)
Voltage magnification in low voltage capacitor
banks, under certain conditions when the HV
Capacitors are switched on
Prestrike arcing in the electro mechanical
switching devices even before the circuit breaker
is closed
Outrush currents that flow during the bus fault
condition
Over voltages may occur if the system is sharply
tuned at one dominant harmonic produced by the
inrush current.
When capacitor bank is taken into service the inrush
currents that flow through the network can cause
protection problems also. The capacitor bank switching
takes place in the electrical network very often if the load
variation is frequent. Every time the switching action
takes place for power factor correction, the travelling
waves will be generated in the network that could (may)
damage high/ low voltage networks of existing Variable
Speed Drives, UPS systems and other existing electrical
equipment [4].
Capacitor switching can be implemented either
through the static switching method or electro mechanical
switching method:
Static switching method of capacitor banks: This
method eliminates the switching transient related
problems and switching can be done in 10ms.
This type of switching systems is quite costly.
For example 5500 kVAR automatic Reactive
power compensation consisting thyristor
switched Capacitor banks IP 23 indoor
application along with its associated transformer
might cost in the range of $837,660/- excluding
the costs associated for cabling, feeder panels,
HVAC and installation.
Electro- mechanical switching: Conventional
electro- mechanical switching breakers with
improved characteristics that suit to capacitor
banks switching are employed in this method. In
comparison to Static switching this switching
method is cheaper and the transient issues are
dealt with separately.
After a detailed interaction with the manufacturers it
has been established that electro-mechanical switching of
International Journal of Electrical Energy, Vol.1, No.1, March 2013
41©2013 Engineering and Technology Publishing
capacitor banks will not pose any threat to the operation
of the Variable Speed Drives and related control
networks. Based on this clarification electro mechanical
switching is considered and recommended in the subject
study.
The specification for Circuit breakers for capacitor
switching can be specified with particular attention to
Transient Overvoltage, Transient Recovery Voltage and
Surge Arrester in accordance with IEC standards.
III. RECOMMENDATION
It is recommended to run all the VSD’s at their full
load, as the power factor at MBIT can be maintained
above 0.91 without any VAR compensation. As the
variations of the loads cannot be controlled due to
shutdowns, planned or unplanned, it is recommended to
improve the power factor at 11kV buses of unit
substations and MBIT.
Based on the above evaluation, Model Number No. 2
is preferred and recommended. This Model number No. 2
is useful for implementation of power factor
improvement scheme for substations where the following
situations are encountered:
Type and nature of the load varies and the
details of load are not available at the time of
PF scheme implementation.
Staggered project schedules will impose a
situation that centralized compensation may
not be feasible.
Selection of centralized capacitor bank with unknown
load and network parameters is generally not
recommended.
Model no.2 recommendation is based on a compromise
or tradeoff between cost and performance based on the
objective defined.
Utility undertaking did not identify the penalty that
will be levied in the event of noncompliance to stipulated
power factor. It is understood and assumed that the
payback period may vary in the range of 3 to 5 years
based on the quantum of penalty that will be levied by
Utility undertaking.
ACKNOWLEDGMENT
The authors wish to thank Ms. Ameena Rajab Team
Leader (Design) and Mr. Jasim Al-Quraini (Team Leader
Power Management) for their support.
REFERENCES
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Industrial Electronics, vol. 46, no. 5, October 1999.
[2] R. Natarajan, “Power system capacitors”.
[3] M. Mcgranaghan, S. Peele, and D. Murray, “Solving Harmonic
resonance problems on the medium voltage system,” in Proc.
CIRED- 19TH International Conference on Electricity Distribution. [4] S. J. Kulas, “Capacitor switching techniques,” in Proc.
International Conference on Renewable Energies and Power
Quality ICREPQ, Spain 15th 17th April 2009.
[5] K. Ellithy, A. Al-Hinai, and A. Moosa, “Optimal shunt capacitors
allocation in distribution networks using generic algorithm – Practical case study,” International Journal of Innovations in
Energy Systems and Power, vol. 3, no.1, April 2008. [6] M. Hamoudi and H. Labar, “Compensation capacitors effect on
harmonics distribution in electrical networks,” European Journal
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Yadavalli Venkata Sridhar is a Specialist Electrical Engineer
associated with Hydro-Carbon Industry for the past 34 years. He is a
post graduate engineer with specialization in Electrical Machines and Industrial drives.
Fakher Al Zalzalah is a Specialist Electrical Engineer associated with
Hydro Carbon Industry for the past 25 years and serving Kuwait Oil
Company in the capacity of Specialist In-charge for Electrical and Instrumentation Systems.
International Journal of Electrical Energy, Vol.1, No.1, March 2013
42©2013 Engineering and Technology Publishing