Internship Report - Rao Saim Zafar

INTERNSHIP REPORT
RAO SAIM ZAFAR Page 1
INTERNEE SMART GRID
INTERNSHIP REPORT
REPORTING HEAD: Mussharraf Hussain, DGM
NAME: RAO SAIM ZAFAR
UNIVERSITY: PAKISTAN NAVAL ENGINEERING COLLEGE (PNEC) –
NATIONAL UNIVERSITY OF SCIENCE AND TECHNOLOGY (NUST)
DISCIPLINE: ELECTRICAL ENGINEERING
DEPARTMENT: SMART GRID
INTERNSHIP PERIOD: Starting Date: 8TH
June 2015
Ending Date: 20TH July 2015

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Table of Contents
ACKNOWLEDGEMENT....................................................................................................................... 3
Power Sector of Pakistan ......................................................................................................................4
KE HIERARCHY SESSION....................................................................................................................8
11-KV Distribution Network.................................................................................................................10
Integrated Business Centre..................................................................................................................12
SMART GRID OVERVIEW ..................................................................................................................13
Oracle-NMS& SCADA Devices ............................................................................................................17
Oracle MDM& AMI.............................................................................................................................24
GIS Software: ....................................................................................................................................... 32
Meter Repair........................................................................................................................................ 33
DISTRIBUTED GENERATION ...........................................................................................................34
UTILITY ANALYTICS..........................................................................................................................36
Partial Discharge Test of Current Transformer .................................................................................40

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ACKNOWLEDGEMENT
I would like express my deepest gratitude and regards to K-Electric for providing me the
opportunity to do internship in the Smart Grid Technology. I would like to avail this opportunity
to express my deepest gratitude to the NMS team, especially my reporting DGM, Mr. Mussharraf
Hussain, Rida Shazli, Shahzeb Zafar, Hassan Zaman, Kamran Kamil, from AMI department
Rehma and Assad for their extensive support and guidance. I am very much thankful to K-Electric
for placing me in the guidance of such competent people.
I perceive as this opportunity as a big milestone in my career development. I will strive to use
gained skills and knowledge in the best possible way, and I will continue to work on their
improvement, in order to attain desired career objectives. Hope to continue cooperation with all
of you in the future

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Power Sector of Pakistan
WAPDA was bifurcated in 2007
WAPDA PEPCO
Responsible for Water Pakistan Electric Power Corporation
and Hydro-Power Development Responsible for the management of all the
affairs of the corporatized - (09) distribution
Companies, 4 Generation Companies and
NTDC
All Companies work under independent Board of Directors (Chairman and some
directors are from the
Private Sector)
NTDC (National Transmission and Dispatch Company):
1. Started working in 1998
2. Operates and Maintains twelve (12) - 500kV and
twenty-one (21) – 220kV Grid Stations
3. 5077 km of 500kV transmission line and 7350 km of
220kV transmission line in Pakistan
NEPRA (National Electric Power Regulatory Authority):
1. Approves tariffs for all Distribution Companies and
approves performance codes/standards for the
Distribution Companies
2. Some of the performance standards are:
a. The distribution company shall supply 95%
of its consumers within the range of +/- 5%
of the nominal voltage and +/-1% of nominal
frequency
b. Following voltages shall be used for
distribution

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i. 400/230V
ii. 11kV
iii. 33kV
iv. 66kV
v. 132kV
vi. 220kV
3. The Company shall supply Electric power to its
customer of the power quality in accordance with
IEEE standards 519-1992 pertaining Harmonic
Content
DISCOs (Distribution Companies):
Pakistan has 11 electric supply Companies, i.e.
1. IESCO (Islamabad Electric Supply Company)
2. PPIB (Private Power Infrastructure Board)
3. AEDB (Alternative Energy Development Board)
4. GEPCO (Gujranwala Electric Power Company)
5. PESCO (Peshawar Electric Supply Company)
6. FESCO (Faisalabad Electric Supply Company)
7. HESCO (Hyderabad Electric Supply Company)
8. LESCO (Lahore Electric Supply Company)
9. QESCO (Quetta Electric Supply Company)
10. K-Electric (Karachi Electric Supply Company)
Power System Structure in Pakistan
Before 2007, Pakistan had a centralized power system structure, but the
centralized power structure had proved not only inefficient, but also
difficult to manage. The figure below depicts the Centralized Power
System Structure of Pakistan

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Due to the inefficiencies and management issues involved in centralized
power system structures, many nations around the world had started
deregulating and restructuring the power system structures to increase
efficiency, curtail losses and to improve management. The de-regulated and
re-structured setup of WAPDA is as shown below
Controlling
Body /
Government
Generation
Setup
Transmission
Setup
Distribution
Setup

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Un-Bundled and re-structured setup of Pakistan
The Un-Bundling and re-structuring of individual companies has made the
management and running of these companies easier, compared to the
centralized system. The above model can be further modified to include
import/export of power from the distributed resources, a concept that is also
known as “Distributed Generation”
Ministry of
Water and
Power
NEPRA WAPDA
Authority
Water Wing
Hydel
Development
Hydel
Operations
Finance Wing
Common
Services
Residual Assets
Autonomous
Bodies
GENCOs (3) NTDC (1) DISCOs (9) IPPs and SSP

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KE HIERARCHY SESSION
KE is owned by Abraaj group since 2008, majority of the shares are owned by
Abraaj group and rest are owned by government. Previous owners of KE
include Siemens, government and Pak army as well. KE has divided Karachi
into four regions, region 2 and 3 are further divided into two sub regions.
KE has an installed capacity of 2400 MW and is provided 660 MW by
WAPDA from the National Grid on fixed pricing, but the generation capacity
is presently 2100 MW as of July 2015. The Peak Demand of Karachi as of June
2015 is 3100MW that was reached due to the heat wave in Karachi in the
month of June. Since KE is experiencing huge losses from the area of Baldia,
Lyari etc. providing continuous electricity supply to these areas is not
economically and financially feasible for the utility. KE has divided areas into
the following categories.
REGION I REGION II REGION III REGION IV
LOW
LOSS
SITE Clifton Bin Qasim Gulshan
Uthal Defence KIMZ
Saddar
Tipu Sultan
MEDIUM
LOSS
LYARI I Bahadurabad Johar North
Nazimabad
Garden Shah Faisal North Karachi
FB Area
Nazimabad
HIGH
LOSS
Baldia Gadap Liaquatabad
Orangi I Korangi Surjani
Orangi II Landhi
Lyari II Malir

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The above table shows the Financial Year 2011 – 2012 depiction of the K-
Electric’s loss areas and generation capabilities.
K-Electric has a vertically integrated system that means it generate,
transmits, and distributes electricity all on its own. The generation voltage
levels of KE are 18kV and 21kV. Transmission levels are 33kV, 66kV, 132kV,
232kV and 550kV (WAPDA). Distribution voltage level is usually 0.4kV and
220 Volts. Generation and transmission are the areas where the company
FY 12
IBC/VIBC
SITE 1,078 5.7% 11,082 99.8% 5.87%
Bin Qasim 1,352 10.9% 7,451 96.0% 14.4%
Defence 641 12.8% 6,409 97.2% 15.3%
Saddar 554 14.8% 5,098 96.9% 17.4%
Clifton 397 16.5% 3,742 97.5% 18.6%
Uthal 567 15.5% 4,002 95.4% 19.4%
Gulshan 445 16.8% 3,898 93.7% 22.1%
KIMZ 631 21.2% 5,437 97.5% 23.2%
Tipu Sultan 523 22.2% 4,297 96.8% 24.8%
Garden 322 24.5% 2,159 91.2% 31.2%
F.B. Area 518 29.7% 3,725 94.1% 33.9%
Bahadurabad 527 27.0% 4,146 90.4% 34.0%
Johar 526 23.1% 3,350 85.6% 34.1%
North Nazimabad 466 31.2% 3,265 94.4% 35.0%
Layari - I 310 26.3% 2,114 86.3% 36.4%
North Karachi 609 30.0% 4,444 87.4% 38.8%
Shah Faisal 485 25.9% 2,233 81.2% 39.8%
Nazimabad 415 43.1% 2,374 80.5% 54.2%
Orangi - I 547 46.8% 2,784 85.5% 54.5%
Baldia 434 50.3% 1,664 81.6% 59.5%
Liaqatabad 369 45.7% 1,977 74.4% 59.6%
Landhi 340 49.4% 1,055 76.7% 61.2%
Layari - II 357 48.6% 1,612 73.1% 62.4%
Gadap 287 50.8% 1,294 72.0% 64.6%
Malir 470 52.1% 2,050 70.8% 66.1%
Korangi 477 55.0% 1,977 74.1% 66.6%
Surjani 397 51.1% 1,725 63.8% 68.8%
Orangi - II 358 61.9% 1,192 74.0% 71.8%
PSC 17,797 77.8%
Distribution 13,322 30.5% 114349.9 88.7% 39.4%
Units Sent
Out
(MWh mn)
Billing
(PKR mn)
T&D
Loss %
Recovery
Ratio %
AT&C

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invests the capital. And distribution department is responsible for generating
revenue for the company.
There are 28 Integrated Business Centers (IBCs) each IBC has four
departments.
1. Customers Accounts (CA)
2. Revenue Protection and Recovery (RPR)
3. Customer Care (CC)
4. Network Customer Center(NCC)
11KV Distribution Network
The electricity at our home has actually been through three major steps,
Generation, transmission and distribution. The transmission of the
electricity from the generation side to the grid station is done at 132kV to
reduce the losses in transmission. Onwards from the Grid station to the sub-
station or ring-main –unit (RMU), the 132kV is step-downed to 11kV. The
distribution network is mainly powered by the 11kV till the PMTs due to
several reasons. One of the major reasons that the distribution network from
the grid station to the PMT is using 11kV because of the reduced losses as
well as the factor that electricity theft is not possible on the 11kV and
therefore the utility, which in our case is KE, use 11kV.
The first feeder with which the main cable is connected is called the Primary
Substation. For KE network, Karachi and its suburbs are divided on
administrative purposes into 4 Regions, i.e. Region I, Region II, Region III
and region IV. The Region II and Region III are further divided into 2 sub-
regions. To handle these in-total 6 regions, 6 have established 6 Operation
Control Rooms (OCRs). Each OCR controls multiple Area Operation Centers
(AOCs). The OCRs are responsible for the 11kV networks, the 0.4V network
maintenance and management is under the control of the Network
Customer Center (NCC).

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The 11kV operations are divided as follows:
11kV Operations
The methodology or the Standard Operating Procedures defined for the
rectification of the Main Cable Fault are:
1. Fault Indication: This step requires the knowledge regarding the fact
that a fault has occurred through Customer Call, SCADA alarms, or
Smart Meter Alarms.
2. Fault Identification: This step is determining of the type of the fault
that has occurred, for example, was it a breaker trip, feeder trip, or
wire/cable breakage, etc
3. Fault Localization: This step is determining or pin-pointing the exact
location of the fault.
4. Back-Feeding: This step is performed to temporarily restore the power
of the effected customers through some alternative source, till the time
the primary source where the fault has occurred is being repaired or
restored.
5. Fault Rectification: Fault removal
DCDO
11 kV Operations OCR
Area Operation
Centers (AOCs)
Mobile
Workforce/Crews
/Gangs
Sub-Station
Maintenance
Control Room
(SSMCRs)
Mobile
Workforce/Crews
/Gangs
Under-Ground
Maintenance
Control Room
(UGMCRs)
Mobile
Workforce/Crews
/Gangs
Corrective
Manager
Preventive
Manager

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6. Restoration: Removal of the fault and rolling back any temporary
measures or action taken on the affected area, and restoring the grid
back to its original state.
Integrated Business Centre
Karachi Electric has established a total of 28 IBCs that is integrated business
centre throughout Karachi as per location of distribution centre that is
Gulshan-e-Iqbal has its own IBC; Gulistan-e-Jauhar has its own IBC and so
on. In accommodation of 28 IBCs KE has established 1 PSC that is Public
Sector Consumer that is open for all the locations prescribed under the
vicinity of Karachi.
IBCs operate under different departments which include
1. New Connection Department
2. Customer Care
3. Customer Accounts
4. Revenue Protection and Recovery
5. NCC
Every department has its designated tasks to perform which they undergo
with set of rules or procedure. Scanning through each department’s task will
be the core study of this section.
New Connection Department
Let’s start by discussing the scenario of a customer willing to take a new
connection from KE, in terms of Karachi Electric it’s a task of putting the
customer on BILLING PANEL. After allocating the customer with the utility
of electricity KE puts up a meter and starts its reading that’s what in
technical terms referred as load enhancement and further goes the billing
procedure of the department. After the billing procedure a term referred as
financial posting is targeted within the department.
Customer care

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Customer care department is considered to be the FACE of KE. Any
customer having an enquiry that is complaint, suggestion or request first
concerns with the department of customer care. A call on 118* actually binds
the channel between the consumer and the utility representative. It is
considered to be the toughest department to have worked in as handling
such remorse issues requires not just skills of a spokesperson but a mind of
peace and fragility of water.
Customer Accounts
Department of Customer Accounts (CA) deals with the billing infrastructure
of the connected consumers. Firstly the meter reading is recorded by a MR
that is Meter Reader, his job is to survey his devised area and to look over all
the meter readings and calculate the amount of units consumed by
subtracting the new recorded reading with the previous recorded reading.
He performs this task in G-Sheets or HHU that is Hand Held Units, the
meters that are being recorded are called as MRU or Meter Reading Units
previously known as sections. And a single survey consisting about multiple
MRUs is considered to be a LOT. Now after MR has recorded the reading he
brings it back to DEO that is Data Entry Officer, he actually punches those
readings into SAP.ISU that is industry specific utility. Screening and different
checks will be performed through this reading and a final bill in printed from
this software. Now different procedure is forecasted when MR would be
unable to get the reading of designated place, which includes average billing
that is if MR is unable to fetch the reading KE bills the consumer on basis of
average units consumed and balances it out under next month reading. Now
the day DEO enters all the reading in the software is considered to be as the
cycle day or now-a-days termed as portions. Such tedious procedure has to
go through for billing a consumer under normal circumstances.
SMART GRID OVERVIEW
A smart grid is a class of technologies that people are using to bring utility
electricity delivery systems into the 21st century, Smart Grid can also be seen
as the computerization of the existing HT and LT network as well as merging
the Information and Communication Technology into the Grid for Real Time
monitoring and controlling of the grid. These systems are made possible by

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two-way digital communications technologies and computer processing. The
purpose of the smart grid technology is to improve the efficiency, reliability,
economics, and sustainability of the production and distribution of
electricity. Electronic power conditioning and control of the production and
distribution of electricity are important aspects of the smart grid
SMART GRID BENEFITST
EXAS Tech University 10
1. Improving Power Reliability and Quality
– Better monitoring using sensor networks and communications
– Better and faster balancing of supply and demand
2. Minimizing the Need to Construct Back-up (Peak Load) Power Plants
– Better demand side management
– The use of advanced metering infrastructures
3. Enhancing the capacity and efficiency of existing electric grid
– Consequently, better control and resource management in real-time
4. Improving Resilience to Disruption and Being Self-Healing
– Distributed grid management and control
5. Expanding Deployment of Renewable and Distributed Energy Sources
– Consequently, better control and resource management in real-time
– Better renewable energy forecasting models
6. Automating maintenance and operation
– Distributed grid management and control
7. Reducing greenhouse gas emissions
– Supporting / encouraging the use of electric vehicles
– Renewable power generation with low carbon footprint

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8. Reducing oil consumption
– Supporting / encouraging the use of electric vehicles
– Renewable power generation with low carbon footprint
9. Enabling transition to plug-in electric vehicles
– Can also provide new storage opportunities
10. Increasing consumer choice
– The use of advanced metering infrastructures
– Home automation
– Energy smart appliances
– Better demand side Management
SMART GRID PRIORTITY AREAS
1. Demand Response and Consumer Energy Efficiency
2. Wide‐Area Situational Awareness
3. Energy Storage
4. Electric Transportation
5. Advanced Metering Infrastructure
6. Distribution Grid Management
7. Cyber Security
8. Network Communications
The KE smart Grid department was established in January 2013 with the
main task of introducing Smart Grid technology in Karachi, Pakistan so as to
enable KE, then KESC, to improve network planning & management while
reducing aggregate technical & commercial losses. The Smart Grid
department has been putting great hard work and effort into
implementation of the smart-grid technology across Karachi. Presently, KE is
implementing 2 smart grid clusters across Karachi. The Cluster – 1 is
established in the North Karachi region and has 9 feeders, S.M Obaid Feeder,
Karaka Pak Feeder, Hassan Cold Feeder, QaimKhani Feeder, Saba Cinema
Feeder, Pole 12 Feeder, Shamsi Garment Feeder, Sheerani Ice Feeder and
Crystal Ice. The Gulistan e Johar is the Cluster – 2 and has smart devices and
meters presently installed on 3 feeders, i.e. Gulshan – e – Amin Feeder, Azim
Garden Feeder and Sunny View Feeder. The HT network has SCADA devices

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installed and the LT network has the smart-meters. All the devices, i.e. smart
meters and SCADA, communicate their data to the Head end devices that
communicates the data to the respective software. KE is presently using the
following softwares for the data and the network management of the Smart
Grid, i.e. Oracle Utilities Network Management System (OUNMS), HX8000
for SCADA Devices, Oracle Utilities Meter Data Management System
(OUMDM), ESRI Geographical Information System (GIS), Oracle Utilities
Business Intelligence software (OUBI), for generation of report generation
and business interface, these softwares are one of the most widely used
softwares around the world in the utilities, the Head End have their own
softwares for communication and management of the data. The Oracle
Utilities softwares have been integrated with the SAP software modules as it
is the Enterprise Resource Planning system (ERP) that has been
implemented in KE. The SAP respective module that are integrated with the
Oracle systems are SAP IS-U B&I (for billing), SAP IS-U EDM (for Loss
Calculation), SAP CRM (for Customer Relation Management) and SAP PM
(for Maintenance).

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Oracle-NMS& SCADA Devices
Oracle NMS is a network management system acquired by the KE for the
integration and management of the KE HT network for smart grid network
management. Oracle NMS provides the user with vast functionalities and
operational support that could provide KE with the key cutting edge benefits
that would allow the KE with the much needed insight, real time
management and fault and error indication of the system. These benefits
combined with the different functionalities and operation abilities of the
system would greatly enhance the capabilities of KE and would allow KE to

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adopt modern business practices at par with those being adopted around the
world.
Oracle NMS has different features such as web management, feeder load
management, outage management system, distribution management system,
crew/gang allocation, tracking of the crews/gangs, notification of different
alarms and events, SCADA along with Fault Location Isolation Service and
Restoration, Fault Location Analysis, etc.. The NMS receives data from
SCADA devices installed in the HT network, because presently NMS is not
being implemented on the LT network. The SCADA devices would allow real
time values and information regarding the current, voltage, VAR, VA and the
threshold limits that have been applied in the systems.
The software also provides different critical features like storm management,
allows simulation (study mode) and “what if” scenarios. The system allows
the replication of the real time situations and values in simulation allowing
the user to test the pros and cons of different actions, as well as the system
would also provide different suggestion and solutions to the user. These
features allow the user to carry out the best possible measure for the
respective issue.
It also allows a satellite view of the HT network spread out via integration
with the GIS software allowing the proper fault indication and network
overview. This feature allows user to have insight in the connection and
location of the different devices, feeders, and substations. NMS allows
creating authority for control zones that would allow a hierarchical structure
with respect to the KE hierarchy.
The power flow analysis, Volt/VAR, suggested switching, and conservative
voltage reduction are one of the few highly important tools that have been
provided in the oracle NMS software. These tools allow a greater level of
control of the grid and the network in the hands of the users and tilt the
direction of the user towards pre-emptive dealing with conditions that could
result in greater faults.

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Power Flow Extensions enable engineering analysis of the electrical
distribution system for use in the operations and control center rather than
for design or planning purposes. They assess the equipment loading and
feeder voltage profiles for selected portions of the electrical network, and
provide overload, fault, and voltage violation information for review.
Suggested Switching helps to generate switching steps for two fundamental
types of scenarios. Switching steps can be generated to restore power to a de-
energized device, or to de-energize and isolate a device that is currently
energized while minimizing the amount of resulting dropped load.
The software produces restoration steps by solving the power flow for each
eligible tie point with adjacent feeders, in order to determine the remaining
feeder capacity and the overloads after the de-energized section is picked up.
Several alternate switching plans may be produced and listed in ranked
order. The user can select the desired switching plan and generate it in Web
Switching Management. When your objective is to isolate a device,
restoration steps are similarly obtained while accounting for the effects of
the switching steps required for isolation of the desired devices.
Volt/VAR Optimization generates a set of optimal substation transformer
tap positions and capacitor bank statuses to minimize power losses and
maintain power quality as the system load changes. Volt/VAR Optimization
also allows you to specify a particular loading scenario against which to
perform the Volt/VAR analysis. Based on the selected load scenario,
Volt/VAR optimization uses the real-time load values or appropriately loads
values from the historic load profile for all load points in the analysis area.
The user-selectable load scenarios are:
•Real-time loads
•Scaled loads
•Peak loads

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•Specific period loads
Feeder Load Management (FLM) is also one of the major tools of NMS that
allows you to manage energy delivery in the electric distribution system and
identify problem areas. Feeder Load Management monitors the vital signs of
the distribution system and identifies areas of concern so that the
distribution operator is forewarned and can efficiently focus attention where
it is most needed. It allows for more rapid correction of existing problems
and enables possibilities for problem avoidance, leading to both improved
reliability and energy delivery performance.
Feeder Load Management is automatically triggered by pertinent changes in
the electric distribution system, such as increased demand or switch status
changes. Feeder Load Management provides dynamically updated views of
closest-in-time alarms, peak loads, and present loads of all the feeders.
Feeder Load Management directs users to those feeders where capacity
margins and/or device limits are at risk or violated.
The purpose of the Fault Location Isolation Service and Restoration (FLISR)
tool is to respond to protection trips of SCADA monitored and controlled
switches (such as the feeder circuit breakers CB and downstream re-closers).
FLISR automatically identifies the faulted section using the protection trip
and Fault Indication flags and then automatically schedules the isolation and
restoration actions to restore the non-faulted areas de-energized by isolating
the fault. It can also present the isolation and restoration actions for
execution by the user. If Oracle NMS Power Flowis implemented, FLISRwill
use power flow analysis in the solution analysis.
In short NMS is a highly applicable and important system that is required to
manage the operation-ability of the smart grid network and to conduct its
monitoring in the real time. Though KE would not be able to implement all
of its operations all at once, because the existing transmission and
distribution setup is quite obsolete and would require massive investment
for up gradation, but installation and integration of the smart devices into

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the existing system would allow real time monitoring of the system but
would also extend the life of the system as it would provide the required
necessary insight into the system and would allow the option of preventive
maintenance rather than being totally blind sighted regarding the grid and
the network. What NMS has to offer for KE itself is quite huge, but what KE
can extract at the moment requires KE to modify its existing operations with
respect to the system with is quite advanced and extensive and provides the
proper example of centralized command and control. The OUNMS is a type
of Advanced Distribution Management and the architecture is shown below.
SCADA Devices:
SCADA
SCADA (supervisory control and data acquisition) is a category of software
application program for process control, the gathering of data in real time
from remote locations in order to control equipment and conditions. SCADA

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is used in power generation plants as well as in transmission and distribution
departments of different utility companies, oil and gas refining,
telecommunications, transportation, and water and waste control.
SCADA systems include hardware and software components. The hardware
gathers and feeds data into a computer that has SCADA software installed.
The computer then processes this data and presents it in a timely manner.
SCADA also records and logs all events into a file stored on a hard disk or
sends them to a printer. SCADA warns when conditions become hazardous
by sounding alarms.
D-SCADA
D-SCADA provides a low-cost modular system option for interaction with
automated and intelligent distribution system field devices. It uses a
simplified data model that is typically generated through an automated
process. The D-SCADA may be implemented to communicate directly with
the field through a variety of methods to meet specific customer
requirements.
D-SCADA includes the following
1. Data acquisition: provides the interface to the system field devices
and ensures data integrity.
2. Inter-Control Center Communications Protocol (ICCP) interface:
provides the ICCP interface that connects D-SCADA to the OMS and
MWFM system. It facilitates real-time data transmission and
reception.
3. Intelligent electronic device (IED) management tools: enables the
user to view and change the status of the data acquisition function’s
objects and the system field devices. They also display IED
communication errors and allow the user to view and reset
communication error counts.
4. Network control executive: handles switching commands from the
OMS and manages their execution.
5. Data archiving interface: directs scanned and derived system data to
an independent long-term archiving system.

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6. Configuration management tool: monitors the status of key
components of the D-SCADA network servers, printers, network
interfaces, true time devices, database domains, etc.
7. Distribution management system: A comprehensive and intricate
DMS is capable of managing fault detection, isolation, and recovery
and Volt/VAR control while interfacing with (or integrating
functionality traditionally found in) distribution SCADA systems,
workforce management systems, outage management systems and
geographic information systems.
K-Electric is using Distribution SCADA system in NMS department of Smart
Grid. The SCADA software that is being used is HX 8000. SCADA devices are
being placed on substation, overhead and underground.
1. DTU: Devices on substation are called Distribution Terminal Unit
(DTUs) model used by KE HXDTU3000.
2. RTU: Remote Terminal Units (RTUs) like Fault Current Indicators
(FCIs) are being placed on Underground and Overhead lines.
3. DCU: The data from the devices installed on Substation, underground
cables and overhead lines is then gathered into a Data Control Unit
(DCU), model used by KE is HXDCU40.
Communication from all the devices installed in D-SCADA system of K-
Electric like the readings from FCI to DCU is being conducted at 2.4GHz
through Zigbee technology.
R
Y
B
DCU
FCIs
DISPLAY
SCREEN

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Oracle MDM& AMI
MDM is the Oracle Utilities Meter Data Management software that is
required for the control and management of the Advanced Metering
Infrastructure (AMI) meters or in simpler words the smart meters. The
purpose of MDM is defined in simpler terms is collection of data and profiles
from different data devices, i.e. meters at different ends and as well as head
ends, and then providing the respective data to the respective systems for
their operations. For example the MDM receives the data from the meters
installed and then would provide the load profiles to the NMS for its
calculation and operations.
K-electric deploys Oracle utilities data management system (MDM) for
storage and acquisition of vast amount of data received through head-end -
system from smart meters. The software imports, validate, store and format
data before making it available for billing and analysis purpose. This
database with its analytical tools is also interfaced with other information
systems like customer information system (CIS), billing system, Outage
management system (real-time outage information from AMI meters),
geographic information system (GIS), and transformer load management.
One of the primary functions of MDM is to implement validation; estimation
and editing on AMI data to ensure that inspire of disruptions in
communication networks or at customer premises, the data sent to the
aforementioned systems is complete and accurate.
The key features of MDM include its capability to provide smart meter
integration with head-end -systems, supports different commodities:
electric, gas, water and others. It has 360 degree user interface that provides
all data related to a device like average usage profile, outage period, meter
reader remarks etc, Facilitate new customer programs by providing multiple
bill determinants rules (like peak demand, time of use, critical peak pricing,
real time pricing).It has usage & event subscriptions so that the data could
be published to downstream systems.

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INTERNEE SMART GRID
MDM has several functional areas
1. Service Provider: A service provider is required for the transmission
and receiving of the data from the meter to the system and from the
system to the meter. For every system there is a service provider, its
function is to either route data from any system to the MDMS (head
end systems have service provider to send info from meters to MDMS)
or from MDMS to any system. (CIS have service provider to receive bill
determinants from MDMS).
2. Device Management: Most devices are meters. Device info includes its
manufacturer, model, head end system which holds record of its
measurements.
Every device has measuring components and the combination of unit
of measure (UOM like kWh), time of use (TOU: on-peak or off-peak)
and Service quantity identifier (SQI: energy consumption or
generation) shows what the device measures. Device configuration
shows how the measuring components are configured.
3. Validate-Estimate-Edit (VEE): The Initial Measurement Data is
recorded and VEE rules are applied on it. The VEE rules validate the
meter reading that whether the reading is matches the historical data
pattern or in other terms performs the sanity check of the reading, in-
case the reading fails the sanity check, and the reading is edited with
the estimated value keeping in view the past trend of the specific
meter readings. Each measuring component is periodically measured.
Each MC has its associated VEE group. When initial measurements are
initialized, VEE rules are applied based on its VEE group & associated
region, device type, customer type, usage pattern.
4. Measurements: The system creates final Measurements once the Initial
Measurement Data has successfully passed the VEE rules. If measuring
component is re-measured, there may be an existence of multiple
readings, but for a specific date & time only one final measurement is
allowed. there are derived values as well like the value calculated after

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distribution loss is calculated or after conversion in different unit of
measure
5. Installation Information: A service point exists for every geographic
location at which a device can be installed; it includes postal address,
geographic identifiers, and other geographic-related attributes that
could directly impacting VEE and usage calculation logics. The
Installation Information also maintains an event history and the
removal date if any so that the system can recalculate the historical
usage
6. Usage Subscription: It is an actually a record of an ongoing request to
calculate billing determinants for one or more service points. It has a
1:1 correlation with a contract in the CIS (that is a system-of-record).
All contractual information that impacts how bill determinants are
calculated is defined on the usage subscription and it is synced with
CIS system that provides the data. CIS is a SAP module used in the
customer accounts.
7. Usage Calculation Rules: The system performs usage calculation rules
on the billing determinants from the usage subscription for a given
time period. The usage calculation rules can be run in the real time
and in the in batch process which is a standard integration in the CIS.
8. Usage Transaction: It records the results of the usage calculations,
which would be sent out to one or more of the participants in the MD,
such as the energy service provider associated with the subscription’s
service point of view. The service point measurement can periodically
“push usage” to the system, whereas the CIS system can also request
usage when it would require calculating the billing determinants.
9. Communication: MDM has inbound and outbound communication is
a record of a messages sent or received by a service provider or by an
MDM participant to / from the head – end or the edge application. The
purpose of inbound and out bound communication is defines below:

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INTERNEE SMART GRID
Inbound Comm.: record of message sent by a service provider,
although initial measurements are true inbound communications yet
they are not regarded as inbound due to their large volumes.
Outbound: record of message sent from MDMs or sent to MDM
participants, while usage transaction is true outbound comm. it is no
considered outbound due to their large volumes.
10. Events: Devices can send/communicate different type of Events, for
example, some of the major events are:
a. “Last Gasp”: If a meter detects power loss is imminent, it sends a
last-gasp message to notify the utility regarding the power failure
or outage condition.
b. “Tamper Detection”: This event occurs when the meter detects
that a consumer or someone is tampering with the meter.
The purpose of meter event is to create or register the interest of
the service provider or utility regarding any ongoing activity or
abnormal condition.
11. Activity: Activity is a record of an event taking place; activity can also
be related to any combination of “master – data” objects.
12. Service Requests: These requests are created to orchestrate
communication sent to the head end systems, such as, a request to
commission a meter, turn a meter off, ping a meter, etc., are all
orchestrated via a service request. The service request can be created
via different methods, for example; services call from an external
system, a user online/ real – time, or a business process.
MDM provide benefits to both utilities and consumers, some of which are
described below:
1. Supports smart grid and smart programs allowing customers to easily
access usage and program information
2. Provides a central data source for all utility departments

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3. Optimizes asset utilization through load aggregation
4. Improves on-time and accurate billing with comprehensive integration
of meter–to-cash operations
5. Aids detection of energy and water theft. Determines effectiveness of
energy/water and conservation programs.
The Graphical representation of the MDM system is as follows:
CIS
Outage Management
Market Participant
Meter and Service Points
Smart Meter Messages
Service Requests
Measurements and Events
Billable Usage
System
System maintains information
about all the meters and the service
points at which they are installed
(the CIS is the system of records)
The system generates service
requests to either enable or
disable the service at the service
points
It initiates business processes that
commissions, decommissions and
monitor the state of the smart
meters
The system is the system of
record for all measurements and
meter events
The system transforms the data
measurements in billable data
that is used by the subscribing
system
Mobile Workforce/Crews
Meter Head
Meter
BTS -
Station
Service
Provider
KE
SERVER

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INTERNEE SMART GRID
© 2010 Oracle Corporation – Proprietary and Confidential
24
Oracle Utilities MDM –
V2 Conceptual Architecture …
Echelon
L+G Meters
Meter Data Management
Device Interfaces
Customer Care
and Billing
Fusion Middleware
Other Systems:
Billing, Work
Management, etc.
VEE Groups
Service Points
VEE
Devices
Usage Sub.
360º Portals Exception Man.
Bill Determinants Custom Rules
Measurement Svcs. Reporting
CSS
BI EE
OU Application Framework
Fusion Middleware & SGG
24
The Oracle MDM software applies Middleware Software fusion and Smart
Grid Gateway to communicate between the Meters, in this case the LANDIS
and GRYS meters, and the Oracle Utilities MDM software. The data from the
meters after being transferred to the Oracle Utilities MDM is extracted by
the Business Intelligence and CSS systems, in this case the Oracle Utilities
Business Intelligence (OUBI) software. The above mentioned systems are
directly integrated with the OUMDM software, but for those systems such as
SAP ERP modules or other Oracle softwares like OUNMS requires
middleware for the fusion and transfer of data from one system to another as
per the requirement of the system.
AMI:
Advanced metering infrastructure (AMI) is architecture for automated, two-
way communication between a smart utility meter with an IP address and a
utility company. The goal of an AMI is to provide utility companies with
real-time data about power consumption and allow customers to make

INTERNSHIP REPORT
INTERNEE SMART GRID
informed choices about energy usage based on the price at the time of use.
AMI is seen as an important part of any smart grid initiative.
K-Electric is purchasing smart meters by
1. IskraMeaco (Slovenia) via TMA (sales agent)
2. Hexing (Chinese) via KBK (local dilution)
3. Holley (China) via IMS (local assembly)
Meters are classified into the following major categories
1. Electrostatic meters
2. Electromechanical meters
Meters used by K-Electric are of the following types
1. Single phase Direct Online Meters
2. Three phase Direct Online Meters
3. CT Operated Meters
4. CTPT Meters
Advance Metering Infra-structure is essentially another department of Smart
Grid. That is responsible for the installation of smart meters, gathering data
from them and enhancing company’s profits and protecting revenues by
applying advanced metering techniques on the basis of data being gathered
from the meters.
Previously there were three ways to access a meter.
1. By meter Reader
2. By the information consumer provides.
3. Meter inspector.
Concept of smart meters has revolutionized the system. These meters can
perform two ways communication which means it sends information
containing any sort of alarm, outage (which is called last gasp information;
the data the meter sends just as its capacitor gets discharge due to outage or

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INTERNEE SMART GRID
shutdown). Etc. Thus advance metering reduces the time and efforts and
increases customer satisfaction because the complaints get resolved quickly.
Smart meters and smart grid cannot completely eradicate theft but the
purpose of installation of these devices is to get an insight of the events on
the field.
Smart meters send interval base data, the interval is set to be of 15 minutes.
The billing period of the meters is set to be of 30 minutes.
The hierarchy of installation of meters is as follows
Feeder Isolation point Distribution t/f Consumer
The data by smart meters then would be integrated directly into the soft-
wares like MDM through which it would be easy to identify the reasons of
energy and positions of faults and outages.
Communication of smart meters is GPRS and GSM based. It has a modem,
and a module in which SIM is connected. KE is using SIMs of Mobilink and
Telenor in there meters.
There are two possible topologies which can be followed, either to have a
SIM installed in every meter which would obviously be expensive, or to have
SIM in only one meter and by using parallel communication connect the
meters to a universal BUS that is RS-485 this would be a much cheaper
option. KE is following the parallel communication topology, which is
further elaborated in the following figure.
METER METER METER METER METER
HEAD
METER
(SIM)RS-485

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INTERNEE SMART GRID
Alarm and Event Communication from meter to the software
GIS Software:
Geographical Information System is used to represent Electrical
Transmission and Distribution network with satellite imaging. GIS helps to
determine
 Current location of different electrical component
 All underground, overhead, LT and HT network present in a system
 How much customers are linked to a feeder or connection
 Every component of the network even the poles are named with an ID
number which helps to locate the component faster in the system.
 Distance between any two components can be determined easily through GIS
 GIS helps to understand the conditions of the network that could help in
installing new component at a particular location.
 GIS even helps in editing as to look for how can a system be designed.
 GIS helps in forecasting the accessibilities that CAN/CANNOT be acquired
within a location.
 GIS could also help in localization and back feeding the network under a
particular feeder.
 For poles it can also indicate the purpose of its position, for example whether
it’s an SHANKLE point or T/OFF pole etc.
Meter Head
Meter
BTS -
Station
Service
Provider
KE
SERVER

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INTERNEE SMART GRID
 GIS serves as the basic parameter for implementation of Smart Grid on the
system.
 It could be very helpful in indicating the location of the fault and forwarding
to rectify the matter faster.
 GIS also helps to identify the strength of a cable connecting a PMT to feeder,
whether it underground or overhead, whether HT or LT.
 It helps in identifying how many PMTs or Poles are connected to a particular
feeder.
 GIS has an accuracy up to -+3m of indicating a network to the original system
planted by the engineers.
 Generally GIS helps in serving the overview of the system, how it is integrated
and how efficiently it can be designed and implemented.
Meter Repair
There are several different types of meters:
1. CT/PT meters on HT
2. CT operated meter on LT
3. Direct Online 1 - ᵠmeters
4. Direct Online 3 - ᵠmeters
There are two categories of meters;
1. Electro-Mechanical Meters: has dials in units of
revolutions/kWh
2. Electro-Static Meters: has impulses with units of
impulse/kWh

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INTERNEE SMART GRID
The meters are tested on the Faulty Meter Report by the meter reader or the
consumer. Several tests are performed on the meter to verify whether the
meter is faulty or not. The types of test performed on the meters are:
1. Dial Test: Revolution test of the meter Dial.
2. Creeping Test: Forward and backwards movement of the
meter dial in the absence of the electric supply.
3. Physical Test: Integrity Check of the Meter
4. Accuracy Test: Test on 1/10 of load, ¼ of load, ½ of load, and
full load.
The Meters are of different Accuracy Classes, i.e. Class-0.5 (0.5% accuracy),
Class-1 (1-% Accuracy), Class-2 (2% Accuracy).
DISTRIBUTED GENERATION
What is Distributed Generation?
Distributed generation (or DG) generally refers to small-scale (typically 1 kW
– 50 MW) electric power generators that produce electricity at a site close to
customers or that are tied to an electric distribution system. Distributed
generators include, but are not limited to synchronous generators, induction
generators, reciprocating engines, micro turbines (combustion turbines that
run on high-energy fossil fuels such as oil, propane, natural gas, gasoline or
diesel), combustion gas turbines, fuel cells, solar photovoltaic, and wind
turbines.
Applications of Distributed Generating Systems
There are many reasons a customer may choose to install a distributed
generator. DG can be used to generate a customer’s entire electricity supply;
for peak shaving (generating a portion of a customer’s electricity onsite to
reduce the amount of electricity purchased during peak price periods); for
standby or emergency generation (as a backup to Wires Owner's power

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INTERNEE SMART GRID
supply); as a green power source (using renewable technology); or for
increased reliability. In some remote locations, DG can be less costly as it
eliminates the need for expensive construction of distribution and/or
transmission lines.
Benefits of Distributed Generating Systems
Distributed Generation:
a. Has a lower capital cost because of the small size of the DG
(although the investment cost per kVA of a DG can be much
higher than that of a large power plant).
b. May reduce the need for large infrastructure construction or
upgrades because the DG can be constructed at the load
location.
c. If the DG provides power for local use, it may reduce pressure
on distribution and transmission lines.
d. With some technologies, produces zero or near-zero pollutant
emissions over its useful life (not taking into consideration
pollutant emissions over the entire product lifecycle i.e.
pollution produced during the manufacturing, or after
decommissioning of the DG system).
e. With some technologies such as solar or wind, it is a form of
renewable energy.
f. Can increase power reliability as back-up or stand-by power to
customers.
g. Offers customers a choice in meeting their energy needs.
Challenges associated with Distributed Generating Systems

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INTERNEE SMART GRID
a. There are no uniform national interconnection standards
addressing safety, power quality and reliability for small
distributed generation systems.
b. The current process for interconnection is not standardized
among provinces.
c. Interconnection may involve communication with several
different organizations
d. The environmental regulations and permit process that have
been developed for larger distributed generation projects make
some DG projects uneconomical.
e. Contractual barriers exist such as liability insurance
requirements, fees and charges, and extensive paperwork.
UTILITY ANALYTICS
 Phase balancing: If power factor of all the three phases are same that
indicates the phases are balanced as power factor is the cosine of phase
difference.
 Voltage analysis: If load voltages of all the three phases are same that
indicates the voltages are balanced.
 Load Balancing: If the line currents of the three phases are not same
that means the load unbalancing has occurred and thus some current
must be flowing through the neutral otherwise the neutral current
must be zero.
Ideally,
I1<0 +I2<120 +I3<240 =IN=0
 Line loss analysis: knowing the conductor material (resistivity), its
length to which it is extended and its cross sectional area the total
resistance of the conductor can be known. Multiplying this resistance
with square of current, line loss can be calculated.

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INTERNEE SMART GRID
Line loss=I2
R where R=PL/A
 Transformer load management: If the customers connected to a
particular PMT are continuously facing tripping or explosions of PMT
that means that the transformer is running on over load. Thus by
summing up the maximum demands of the consumers a PMT should
be installed of such rating that it does not trip.
∑Customers Max Demand< PMT rating
 Unit Difference analysis: The difference of the power provided by
the PMT to a particular area and the sum of total power consumed by
the customers connected to that PMT. If an enormous difference is
observed in these two measurements then that means the company is
facing loss.
∑KW PMT-∑KW Consumer=Δ
 Feeder load management: If the feeder of a particular area is
tripping frequently that means it is being overloaded. Sum of all PMTs
connected to a single feeder must not exceed the feeder’s maximum
capacity in order to avoid tripping.
∑Rating of All PMTs < Feeder Maximum Capacity
 Fault current: If any fault current is detected by FCIs it can be
observed on the data table. Any abrupt rise in current means that a
fault has occurred. Fault current is normally 6 times the nominal
current.
X up to fault-1
*100
 Fault location analysis: On the basis existence of fault current on the
data sheet, we can know location of the fault that on what patch fault
has occurred. And how many consumers are affected of that particular
area.

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 Short circuit KVA: The magnitude of short circuit fault current
multiplied by voltage of the line before occurrence of fault can be used
to calculate the short circuit KVA of the asset. And thus we can know
the capacity of the instrument
Short Circuit KVA= Post fault current * pre fault voltage
 Asset utilization monitoring: Assets can be defined as any device or
instrument that is important to the company. It can be a meter, PMT,
or any device. Through the data we can see if the PMT is running on
overload so it can be changed before exploding etc.
 Power factor analysis: Lesser power factor causes burden to the
utility company and also to the consumer as consumer always pays for
active power consumption lesser power factor indicates that it is using
more reactive power. The data indicates the different values of power
factors, it is thus easy for the company to impose penalty on the
consumer if its power factor is less than 0.85.
 Outage minutes validation: The data can provide us with the
duration of outage, formula for outage duration can be expressed as,
Duration= Power Up (time/min) - Power Down (time/min)
 Outage dollarization: The amount of revenue lost by the utility due
to outage. For example, 4000 customers are effected due to outage of 4
hours with 15 Rs per unit cost and an average of 1.5kWh per house. The
revenue lost by the company in that 4 hours will be 3lac 60thousand
rupees.
Outage Dollarization (Rs) = No. of outage hours*no of consumers
under outage*per unit cost*average energy consumed per hour
 Customer segmentation: On the basis of the data consumers can be
categorized into different segments. For example, the area from which

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INTERNEE SMART GRID
the revenue is not being regained by the company or the utility
company is facing loss. The consumers of that area can be segmented
into high loss similarly category of medium loss and low loss can be
designed.
 Diversion and back feeding: Knowing load of the PMTs connected
to a particular feeder, we can devise a diversion plan or back feeding
pattern during outage. Let suppose that if a feeder has capacity of
10,000 KVA and the summation of all the PMTs connected to it are
8000 KVA, which means if there is outage in any other area so the
2000KVA load of that area can be fed through this feeder.
Feeder Capacity-∑PMTs rating= Back feeding Capacity
 Events and alerts: Alerts and events can be identified by the current
flowing through the system, system voltages, power factor and
apparent power. When the total KVA rating not equals to the
consumed KVA rating of the system there is said to be theft present in
the system. Other alerts such as temper alerts in meter can be
identified through a notification from the meter.
 Load profile analysis: Load profile analysis can be performed by the
voltage, active and reactive power consumed by the system by
constructing the graph of present values and indicating the Max
Demand, Utilization factor etc. concerning the system.
 Demand Factor: Consumers do not use all the devices at full load
simultaneously. Maximum demand for each consumer is therefore less
then total connected load.
Demand Factor= Max Demand/ Total connected load
Demand factor is usually less than 1.

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 Average Load or Average Demand: From the data average demand
can be calculated in a particular time interval. As it is the ratio of
energy consumed in a given time period
Av. Load=Energy Consumed in a given period/Hours in that time
period
 Diversity Factor: Maximum demands of individual consumers are not
likely to occur simultaneously, so there is diversity in occurrence of
load. Large diversity factor has the effect of reducing the maximum
demand, consequently lesser plant capacity is required, thus capital
cost is reduced and the cost of generation is also reduced.
Diversity Factor= Sum of individual maximum demand/coincident
max demand of whole system
 Utilization Factor: Maximum Demand/Rated System
capacity
Partial Discharge Test of Current Transformer
Partial discharge is a localized dielectric breakdown of a small portion of a
solid or fluid electrical insulation system under high voltage stress, which
does not bridge the space between two conductors.
1. Reasons
PD level over 2,500pC (in paper) and over 10,000pC (in oil) may be
destructive ionization
a. Insulation Degradation (Reversible)
i. Conductive mode particles, bridges gap in oil insulations,
causes 100pC to 10,000pC
ii. Increased moisture content around 3-4% resulting in
concentration of the moisture in oil; also causes reduction
in PD inception voltage by approx. 20%, resulting PD
discharge 2,000 – 4,000pC.

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INTERNEE SMART GRID
iii. Poor impregnation, resulting PD discharge 1,000 –
2,000pC.
iv. Air gas bubbles (3 – 5mm), resulting PD discharge 1,000 –
10,000pC.
b. Oil Barrier Insulation break-down (Irreversible)
i. Breakdown of oil gap; apparent change 10,000pC and rises
rapidly to 100,000 – 1,000,000pC
ii. Incipient carbonizing the cellulose (heating over 300C);
corresponds to several charge pulse of 100,000 –
1,000,000pC
c. Creeping Discharge
i. Splitting oil molecules under effect of sparking. Formation
of hydrocarbons followed by formation of carbonized
traces in pressboard. Lowering of PD magnitude to 1,000 –
5,000pC
d. Failure of turn – to – turn insulation
i. Sporadic PD pulses of magnitude 400 – 1000pC
ii. Rises up to more than 100,000pC
2. Sources of PD generation
Components Sources of PD Typical Faults
Core and coil Assembly
oil-barrier-paper
structure and oil
Electrostatic Shields
Leeds
Operating Voltage
PD attributed to
reversible change of
insulation condition
PD attributed to the
irreversible
degradation of
insulating material
Oil/surface
contamination with
particles, bubbles,
static
electrification, bad
impregnation,
high moisture,
Partial breakdown in
oil; surface
discharge; creeping
discharge

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INTERNEE SMART GRID
Sparking and arcing
between bad
connection
“Conductor under
floating
potential” discharges
Tracking in wooden
blocks
PD associated with
voltage induced by
main
magnetic flux
PD associated with
voltage induced by
stray
flux
closed loops between
adjacent
members linked by the
main flux
(insulated bolts of core,
pressing
bolts, pressing metal
rings, etc);
sparking due to
floating potential
closed loops between
adjacent
members linked by
stray flux;
floating potential (e.g.
ungrounded magnetic
shunts)
Bushings Operating Voltage Localized defect within
the core:
bad impregnation, high
moisture,
short-circuits between
layers,
sparking across the
core surface
Breakdown in oil;
surface discharge
across the

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INTERNEE SMART GRID
porcelain
LTC Operating voltage
PD associated with
operating voltage at
the
fix tap position:
PD associated with
switching process
Partial breakdown in
the selector
and in the diverter
switch
compartment
Poor or worn out
contacts
3. Methods of PD detection
Type of sensors Advantages Disadvantages
Electric
Direct connection to the
test
tap,
or through high
frequency
CT on the grounded
wire,
(“Rogovski coils”)
Additional sensors in bus
duct, electrostatic
shields,
neural etc.
High sensitivity
Can be calibrated in
terms of
apparent charge
Approximate location
of PD
source
All capabilities to
trend data
Use of PD pattern
Recognition
technology
Sensors configuration
can
match for better noise
rejection
De-energizing for
sensors
installation
Electro-magnetic
(Antenna)
RF
UHF
Easy to use
Possible assessing
external PD
problems including
PD in the
bushings
Serving as a noise
(corona)
channel
High disturbances
Only discharges of
extremely
high level can be
detected
Difficult to
distinguish an
equipment having
problems

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from surrounding
equipment
Acoustics
Piezo-accelerometer
placed
on transformer tank
Easy to install
Capability detecting
acoustic
emission magnitude
and trend,
Pulse repetition rate
and trend
Localizing a source of
PD
Low sensitivity
Minimal detecting
apparent
charge >10,000pC
Responded to rain,
sleet,
electrical disturbances
in the
4. Transformer Tests
i. Accuracy Test
ii. Dielectric insulation tests
iii. Temperature rise tests
iv. Short time current tests
v. Verification of terminal markings and polarity
5. Standards
Standard Standard Number Year
Indian 2705 1992
British BS EN 60044-1 1999
International
Electro-technical
Commission (IEC)
IEC 60044-1 2000
Australian AS 1675 1986
Australian AS 60044-1 2007
American ANSI C.57.13 1993
Chinese CNAS-PD20/09-B/1
Ref: ISO/IEC 17025

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INTERNEE SMART GRID
6. Typical specification for a 11 kV CT
a. System voltage:11 kV
Insulation level voltage (ILV) : 12/28/75 kV
Ratio: 200/1 - 1 - 0.577 A
Core 1: 1A, metering, 15 VA/class 1, ISF<10
Core 2: 1 A, protection, 15 VA/5P10
Core 3: 0.577 A, Class PS, KPV>= 150 V, Imag at Vk/2 <=30 mA,
RCT at 75 C<=2 ohms
Short time rating:20 kA for 1 second

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Internship Report - Rao Saim Zafar