td rowspan=2 width=10 nowrap> « back to results for ""
Below is a cache of http://www.eei.org/meetings/nonav_2006-10-08-ec/Mon-Greenen.pdf. It's a snapshot of the page taken as our search engine crawled the Web.
The web site itself may have changed. You can check the current page or check for previous versions at the Internet Archive. Yahoo! is not affiliated with the authors of this page or responsible for its content.
Microsoft PowerPoint - Mon 12 - Greenen 1
Transformer Monitoring at
ITC<i>Transmission
July 28, 2006
2
Agenda
Who We Are
Project Background
Experience to Date
Questions 2
3
Who We Are
4
ITC<i>Transmission is the first independently owned and operated U.S. transmission company
February 2003 - became independent through acquisition by International Transmission Holdings L.P.
(KKR & Trimaran primary investors)
ITC Holdings became a publicly traded company on the NYSE on July 26, 2005
Transmission rates are FERC regulated
Formulaic rate design adjusts annually for capital investments, recoverable expenses and load
High concentration of industrial customers in service area
Require elevated levels of reliability
Supportive of industrial improvement projects
Serves as Conduit Between Generation and
Distribution Customers
Attractive Service
Territory
Company Overview 3
5
Transmission is Our Only Business
ITC<i>Transmission focuses on ownership, operation,
maintenance, and construction of transmission facilities as
a single line of business.
There is no internal competition for capital it is dedicated for
prudent transmission investment.
Because of our singular business focus, we are aligned
with customers.
Customers benefit from transmission investment by:
Improved reliability
Reduced congestion
Increased access to generation.
6
On May 12, 2006, our parent
company, ITC Holdings Corp.,
announced that it had signed a
definitive purchase agreement to
acquire all of the ownership
interests of Michigan Electric
Transmission Company (METC)
Upon closing ITC Holdings will own
100% of the interests in METC
Transaction valued at approximately
$866 million to be financed through a
combination of cash and ITC Holdings
common stock
Transaction requires both FERC
and anti-trust approvals
FERC approval anticipated by August
2006
Expected to close in second half of
2006
METC Acquisition 4
7
150+
$612 million
Midwest ISO
16
16,000+
155
More than 2,700
Southeastern Michigan
12,745 MW
Novi
March 2003
90+
Employees
$397 million
2005 Ratebase
Midwest ISO
Membership
21
Interconnections
93,000+
Transmission Structures
81
Stations
Approximately 5,400
Total Transmission Miles
Lower Peninsula of Michigan
Service Area
9,841 MW
System Peak Load
Ann Arbor
Headquarters
May 2002
Founded
ITC<i>Transmission/METC Comparison
8
Geographically contiguous
More efficient planning, construction
and operations
Consistent with FERC vision to
advance independent transmission
company business model
Increased investment in transmission
system
Similar regulatory constructs
Increased Industry Presence
Creates largest independent
transmission company in US
(1)
Over 20,000MW combined peak
load, about 15% of Midwest ISO
peak load
Creates 10th largest transmission
serving entity in the country
(1)
(1) Based on annual electric retail sales in the service territory as found in Edison Electric
Institute Profile: Rankings of Shareholder-Owned Electric Companies, April 2005.
METC: An Optimal Acquisition 5
9
ITC Great Plains and ITC Great Plains
ITC Grid Development, a new subsidiary of ITC Holdings
Corp., was formed in order to address national need of
increased investment in transmission infrastructure.
ITC Grid Development will tap into experience and existing
relationships held by ITC<i>Transmission and partner with local
regions to bring identified projects into construction and ultimately
into service.
Through the establishment of ITC Grid Developments
subsidiary ITC Great Plains, the first region of focus is the
Kansas/Great Plains area:
Significant state and regulator support for transmission investment
due to recent shift from serving as energy exporter to now as
energy importer
Sizeable generation pricing disparity between western and eastern
Kansas
Growing interest in capitalization of wind potential
10
Transformer Monitoring Project
Background 6
11
Initiated in 2002 after a series of large power transformer failures
Coventry Station 345/120 kV 300/400/500 MVA catastrophic failure (1998)
Bunce Creek 230/120 kV 300/400/500 MVA catastrophic failure (2001)
Navarre Station 230/120 kV 300/400/500 MVA catastrophic failure (2001)
Although the project had been started in 2002, another failure of a
675 MVA, 230 kV Phase Shifting Transformer in 2004 provided
further justification
Transformer Monitoring Project
12
First approach: Discrete devices
Initial Project design would use discrete devices for:
Bushing Monitoring
Temperature Monitoring
DGA Monitoring
Device integration and communications had to be designed
Site specific communications to get data from field units to control house
Pilot design developed, but required validation before installation
New Telecommunication being installed at ITC stations had to be
incorporated into design
Design approach was rejected
Re-evaluated devices and selected GE TMedic as an integrated device
Transformer Monitoring Project 7
13
Project Steps
Scope
Design
Construction
Commissioning
Training
Transformer Monitoring Project
14
Scope
Installation of TMedic system on all existing and future system
transformers
TMedic unit
Accessories including temperature and current monitoring
Hydran M2
Doble IDD bushing monitoring system
Individual transformer alarm annunciation
Engineering, procurement, construction and management of the
project was outsourced
Transformer Monitoring Project 8
15
Design
Since existing transformers were built by a variety of manufacturers,
there were several physical design questions to address:
How will the cooling system be monitored?
Depending on manufacturer and design, a number of fan/pump wiring
combinations exist
How will the Hydran M2 be mounted on the transformer?
Availability of suitable locations is different among transformers
What kind of bushings are on the transformer?
There are different Doble IDD sensors for different bushing tap types
Transformer Monitoring Project
16
Result: Different manufacturers have different configurations
Design consolidation is limited and results in individual designs
Future transformers are specified with TMedic accessories and pre-
wired in the factory to simplify field installation
Doble IDD sensors
Hydran M2 unit
Monitoring devices for cooling system current (fans, pumps) and load current
Auxiliary relays for breakout of individual alarms
Transformer Monitoring Project 9
17
Construction
Most of the installation of the TMedic system can be accomplished
while the unit is in service.
Use of clamp-on current transducers eliminate need to interrupt CT circuits
Temperature sensors attach magnetically to tank wall for easy installation and
flexibility in location choice
Future units are specified with top and bottom thermometer wells for TMedic
temperature measurements
Hydran M2 is installed on a convenient valve
Typically the drain valve if a more suitable location is not available
Future units are specified with Hydran placement in the oil flow path of the oil
pump (A more ideal location)
Exception: Doble IDD sensors must be installed during an outage
Transformer Monitoring Project
18
Transformer Monitoring Project
Clamp-on Transducers for Load Current Monitoring
Monitoring of HV
side load current
Window-type
transducers allow
for on-line
installation
without
interrupting
current path 10
19
Transformer Monitoring Project
Clamp-on Transducers for Cooling System Monitoring
Transducers
are measuring
current of
cooling fan
motors
20
Transformer Monitoring Project
Temperature sensor Top Oil Temperature
- Magnetically
mounted and sealed
with RTV to prevent
water ingress 11
21
Transformer Monitoring Project
Hydran M2
Hydran M2 is
mounted in this
application near the
base of the unit on
an auxiliary valve
22
Transformer Monitoring Project
Doble IDD Bushing Monitoring
System
Doble IDD sensor attached
at bushing tap 12
23
Commissioning
Local check-out
Wiring for alarms, etc. are verified at the station
Transformer and TMedic alarm points are programmed in the station annunciator
via the station RTU for local alarm indication
Completed by engineering design contractor
Transformer Monitoring Project
24
GE Commissioning
Creation of Technical Query (TQ) nameplate and test report information is
gathered for variables needed in configuration
Typically done 4-6 weeks before commissioning
D25 RTU Configuration TQ data is loaded