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 WingHydel

Development

Hydel Operations

Finance WingCommon 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

LO

W

LO

SS

SITE Clifton Bin Qasim Gulshan

Uthal Defence KIMZ Saddar

Tipu Sultan

ME

DIU

M

LO

SS

LYARI I Bahadurabad Johar North Nazimabad

Garden Shah Faisal North Karachi

FB Area

Nazimabad

HIG

H

LO

SS

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 OCRArea Operation Centers (AOCs)

Mobile Workforce/Crews

/Gangs

Sub-Station Maintenance Control Room

(SSMCRs)


/Gangs

Under-Ground Maintenance Control Room

(UGMCRs)


/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 – Better monitoring using sensor networks and communications – Consequently, better control and resource management in real-time 4. Improving Resilience to Disruption and Being Self-Healing – Better monitoring using sensor networks and communications – Distributed grid management and control

5. Expanding Deployment of Renewable and Distributed Energy Sources – Better monitoring using sensor networks and communications – Consequently, better control and resource management in real-time – Better renewable energy forecasting models 6. Automating maintenance and operation – Better monitoring using sensor networks and communications – Distributed grid management and control 7. Reducing greenhouse gas emissions – Supporting / encouraging the use of electric vehicles – Renewable power generation with low carbon footprint

https://en.wikipedia.org/wiki/Sustainability

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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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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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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


Meter Head

Meter

BTS -

Station

Service

Provider

KE

SERVER

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© 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

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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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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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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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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 - ᵠ meters

4. Direct Online 3 - ᵠ meters

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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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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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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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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Line loss=I2R 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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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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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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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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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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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

Internship Report - Rao Saim Zafar

Documents

smart grid internship

smart grid technology

smart grid overview

rao saim zafar university

shahzeb zafar

mussharraf hussain

reporting dgm

deepest gratitude