2006 Substation Workgroup Meeting WESTERN ELECTRICITY ...

2006 Substation Workgroup Meeting
WESTERN ELECTRICITY COORDINATING COUNCIL
Vancouver, Washington
May 1-3, 2006
WECC Substations WG Meeting Minutes, May 2006 Page 1 of 13

W.E.C.C. SUBSTATION WORKING GROUP MEETING 2006
ATTACHMENT A: Summary of 2005 / 2006 Trouble Reports
ATTACHMENT B: Complete 2005 / 2006 Trouble Reports
WECC Substations WG Meeting Minutes, May 2006 Page 2 of 13

2006 WECC Substation Workgroup Meeting Agenda
Conference Hosted by PacifiCorp and Bonneville Power Administration
Conference Will Be Held In the Chinook Room
SUNDAY 5:00pm – 8:00pm EVENING RECEPTION- Hotel Mezzanine
April 30
Hosted by PacifiCorp
MONDAY 08:00 INTRODUCTION OF MEMBERS AND GUESTS
May 1
WORK GROUP BUSINESS
A. Review agenda
B. Review minutes of 2005 meeting
C. Discuss time and location of 2007 meeting
D. Update attendance/mailing list
08:30 Discussion of Theft of Substation Grounds
09:00 SAFETY / ACCIDENTS / NEAR MISSES
09:30 Discussion on Animal Protection in Substations
10:00 TROUBLE REPORTS
A. Transformers
B. Circuit breakers
C. Surge arresters
D. Insulators
E. Disconnects and circuit switchers
F. Bushings
G. PTs and CTs
H. Capacitors
I. Reactors
J. Miscellaneous equipment
12:00 Lunch
1:00 Continue Trouble Reports
3:30 GridAlert Plus - New WECC Trouble Reports – Steve Larson
4:30 Adjourn
TUESDAY 08:00 Load Tap changers and DGA’s - PacifiCorp
May 2 10:00 Cascade Maintenance Management System – Digital Inspections
11:30 Lunch
1:30 Portable DGA Testing- Transport X- Kelman
2:30 Where We’re Going Since Westwing Fire- Arizona Public Service
3:30 TOA Program for DGAs – Metropolitan Water District
4:30 Adjourn
WEDNESDAY 8:00 Copperweld Conductor – Shane Zehnder
May 3
Discussion of SWG Emails Over the Past Year – Tom Thee
10:00 Service Advisories
Performance of equipment vendors
Repair facilities
Maintenance procedures
Regulatory Issues: OSHA, EPA
Miscellaneous
11:30 CLOSING COMMENTS
12:00 ADJOURN
WECC Substations WG Meeting Minutes, May 2006 Page 3 of 13

Substation Work Group Charter
1. Review and analyze EHV and related lower voltage equipment trouble reports.
2. Document and distribute information to the Subcommittee members on equipment
deficiencies, modifications and corrective measures and make available to other
member systems.
3. Share O&M information from equipment manufacturers throughout the work group
and make available to member systems.
4. Review operation experience relative to equipment application.
5. Review instrumentation, tools and equipment being offered for use on EHV and lower
voltage equipment for maintenance and operation. Solicit reports regarding
experience in using this equipment.
6. Provide a forum for discussion of solutions to unusual maintenance problems that
have been experienced.
7. Provide information and spare parts assistance in second contingency situations to all
member companies and maintain current procedural information such as contacts in
each company or agency.
8. Exchange maintenance procedures, schedules, instructions, and methods for routine
and emergency maintenance functions.
9. Review safer working practices and assist in development of procedures and
instructions.
10. Review equipment and insulating medium specifications of member companies or
agencies.
11. Review and update WECC Voltage Matrix every two years.
WECC Substations WG Meeting Minutes, May 2006 Page 4 of 13

WECC Business
Tom Thee called the meeting to order on Monday, May 1. Minutes from the meeting of May
2-4, 2005 were approved. Tom Thee mentioned that we have not yet obtained a host utility
for the 2007 meeting, although Xcel (Public Service Colorado) and WAPA might cooperate
on hosting the meeting in Denver.
Past, Present, & Future Meeting Locations:
1986 Denver, CO 1987 San Diego, CA 1988 San Diego, CA
1989 Portland, OR 1990 Phoenix, AZ 1991 Spokane, WA
1992 Tucson, AZ 1993 Vancouver, BC 1994 San Ramon, CA
1995 Denver, CO 1996 Rapid City, SD 1997 Albuquerque, NM
1998 San Diego, CA 1999 Phoenix, AZ 2000 Park City, UT
2001 Las Vegas, NV 2002 Colo. Springs, CO 2003 Bellevue, WA
2004 Rancho Mirage, CA 2005 Boise, Idaho 2006 Vancouver, WA
2007 Not yet determined 2008 2009
Trouble Reports
The trouble report summary with tables/graphs and a CD/ROM with the detailed reports and
digital photos were distributed. The 2003. 2004, 2005, and 2006 reports are on the CD, but
prior year’s reports were paper-based. Members discussed their failures, some items of
special interest were:
• Avista #2, violent arrester failure damaged NLTC gearbox on transformer.
• BC Hydro #2, breaker failed to interrupt reactor load current, caught fire.
• BPA #6 & #9, internal fault from corona shield to interrupter on 500 kV breaker
• BPA #8, breaker failed to interrupt fault near remote bus.
• BPA #16, extreme gassing in 500 kV reactor
• MWD #1, transformer had burned internal connection near bushing termination
• PSC #2, catastrophic transformer failure caused by severely undersized leads installed
when transformer was re-wound in 1998.
• PSC #3, bushing on mobile sub failed, causing transformer failure. Mobile sub was
total loss.
• PSE #1, transformer had turn-to-turn short after lightning strike.
• PSE #2, transformer failed (ruptured B-phase winding) due to animal-caused throughfault.
Theft of Substation Grounds
Theft of substation grounds was discussed by the group. Mike Mundo mentioned there were
several instances of theft at LADWP, including bus pipe. LADWP has also used stronger
fencing material to keep out intruders. Their security department has installed security
cameras at stations which can be monitored remotely and alarmed. He mentioned “removing
the bait” is important, do not leave valuable equipment easily removed in full sight. They
also work with law enforcement agencies to monitor large-size wire coming into scrap
dealers.
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Several utilities discussed use of security cameras in the substations, accessible from the
control center. PSE (Gary Veach) mentioned that recording needs to be matched with
monitoring, otherwise it just documents incidents without prevention. The vast majority of
intrusion alarms are false alarms, so PSE does not call police, just send a substation inspector.
They are also installing a sensor wire (alarming) woven into the substation fence fabric that
provides detection if the fence is cut. BC Hydro (John Robertson) mentioned they have 2-3
intrusions per week. Some are professional, but many are amateurs who clip off any exposed
copper. John said they have added mesh fencing to make entry more difficult and they are
beginning to use Copperweld (a copper-clad steel cable) for the substations. Painting the
copper conductor might also be effective in reducing visual signs of copper in existing
stations.
Tom James from PG&E said they have begun using identifying markings on their copper
wire, and are using Copperweld to deter theft. SCE (Tony Bustamonte) has capability for
video monitoring at all large stations, and a fabric built into the fence that detects intrusions.
CSU (Scott Marshall) has a security center that monitors facilities. Pacificorp (Tom Thee)
has security cameras at some substations, but they don’t always work right. They are also
trying “data dots” (made at Identification Technology Corp, Issaquah, WA) to identify their
wire if it’s brought in to a scrap dealer.
SRP (Dave Monday) has had many entries, and they have found vandals are cutting the ties
and getting under the fence rather than through it, which makes entry harder to detect. Chris
Zacharia (SnoPUD) asked if any utilities were using “Cyberlock”, which is a recently
developed locking system that identifies dates, times, and personnel who enter the station. No
WECC utility members reported that they are currently using the Cyberlock. A Copperweld
sample was passed around and some discussion occurred about attaching, splicing, applying
grounds, etc.
Safety Reports
• IID (Al Minor) reported an employee touched the fence in a substation after the
grounds had been stolen and received a shock. Pacificorp (Tom Thee) mentioned a
similar incident where ground current went through a control cable because grounds
were missing in the station.
• PGE (Larry Heath) had a 115 kV potential device violently explode in an energized
yard where the crew was working, although the crew was far enough away that they
were not affected.
• SCE (Bryan Fridlund) reported an accident where an employee accidentally got their
finger into a running fan on the transformer and cut it off.
• LADWP (Michael Mundo) reported an accident during work on a battery system
where the employee was injured.
• SRP (Dave Monday) reported a line inspector that fell down a 30’ cliff during tower
patrol, and was badly injured.
• AVA (Craig Lancaster) initiated a new safety program where any incidents or close
calls are posted for all to see.
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• SCE (Tony Bustamonte) began a stretching program to reduce injuries for field crews
(transmission, distribution, & substation)
• SRP (Dave Monday) asked about fall protection on transformers, and several utilities
responded with their practices. APS is using Loctite epoxy to attach brackets rather
than welding.
• PGE (Larry Heath) has built a simulator for rescuing someone from a transformer.
• A quick show of hands was taken to determine which companies are equipping crew
trucks with AED’s, and about half of them do this.
• General discussion about fall protection, and using a “maypole” compared to the
“boxing ring”. A quick poll on fall protection during equipment testing showed there
is no consensus about exemption from fall protection during testing.
• Pacificorp (Tom Thee) discussed changes to their company’s safety programs.
Animal Protection in Substations
PGE (Jesse Duffy) has tried out an electric fence that is placed around certain substation
equipment where they have experienced animal problems. The charger puts out a DC voltage
that keeps animals out. They also tried an animal fence (not electrified) that was difficult to
install & maintain, so they discontinued use.
SRP (Dave Monday) asked about bird protection. They have tried products, but none seem to
work well. PG&E (Tom James) and WAPA (Rich Perry) replied that outdoor capacitor banks
were attractive to starlings, and have used “hazing guns” to discourage flocks of birds. APS
is experimenting with a trained hawk to discourage birds from congregating at the station.
DGA’s of Tap Changers
Mark Sampson (Pacificorp) gave a presentation on DGA’s for tap changers. Pacificorp had
several failures annually of transformers due to LTC problems, so they implemented a
quarterly DGA testing program to better monitor the internal status of the LTC and catch
problems before a failure would occur. A LTC failure is always very costly and about one of
every 20 LTC failures leads to transformer main-tank failure also. DGA sampling on a
routine basis can predict internal condition of the LTC with reasonable (but not perfect)
accuracy.
There are many factors which affect the DGA results, such as type of switching, venting,
recovery voltages, age of oil, loading, number of operations, etc. The DGA is analyzed by
looking at:
• Arcing gasses (mainly acetylene) are impacted by speed of operation, recovery
voltage, and arcing tip wear.
• Heating gasses (methane, ethane, and ethylene) are created through coking, which is
generated by I 2 R losses from impedance of leads & contacts. The heating gasses are
developed through high resistance contacts producing heating and coking.
Mark discussed limits of gasses in a LTC at which we should be concerned about the tap
changer’s condition:
WECC Substations WG Meeting Minutes, May 2006 Page 7 of 13

Type Acetylene Methane Ethane Ethylene
Vacuum 5 100 50 200
Resistive 5000 300 200 600
Diverter 8000 750 500 1500
Non-Diverter 12000 1200 750 2200
However, these threshold values are often misleading, and it’s important to consider ratios
between gasses as well. One key is to look at the acetylene to ethylene ratio. If ethylene
exceeds acetylene, this is a strong indicator of coking. The arcing-type tap reactive changers
should produce acetylene with some heating gasses. Resistive tap changers produce high
acetylene with less heating gasses. A resistive type LTC will produce very high acetylene if
the current interruption has slowed. Mark has diagnosed several roller bearing problems on
UZD & UZE type LTC’s that were not visually evident but produced high acetylene on the
DGA tests.
Mark had some advice for LTC best practice operation:
• Vent LTC’s and install desiccant breathers
• Test and inspect LTC’s before energizing
• Install oil filters but don’t expect them to eliminate coking
• Vacuum process all LTC’s above 350 kV BIL and GE LRT-200, LRT-500, &
Westinghouse UVT’s
• Do a routine check of LTC to main tank differential temperature
• Maintenance based on time and operations
• LTC’s should operate through neutral
• LTC design – smaller multiple contacts are much better than large single contacts.
• Inspect all contacts closely
• Change out bad oil
• Make sure operations count is within normal range
• Do not operate LTC’s that are suspect
• Most failures occur on non-wiping contacts, like reversing switch and collector ring
contacts
• Ethylene should be lower than acetylene, the values may increase as the oil ages and
loading increases, but the ratio should remain close to the same.
Using Software to Improve Maintenance Practices
Dennis Washburn from Digital Inspections discussed how software can be used to improve
maintenance practices for substation equipment. The objective for substation maintenance is
to:
• Ensure safe and reliable operation of equipment assets
• Meet regulatory compliance
• Improve availability & reliability
• Maximize return on the investment, through life extension and avoiding failures
• Manage the maintenance costs
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Maintenance can be reactive, preventative, or predictive. Reactive maintenance may be “run
to failure” or wait until problems occur. Preventative maintenance may include some time
and/or operations criteria for when to initiate maintenance work. Predictive maintenance may
include diagnostic or condition assessment tools that enhance ability to optimize timing of
maintenance activities. All maintenance involves decisions prioritizing which equipment to
maintain, balancing resources and backlog, and those decisions require information and data.
Software can be used to improve maintenance practices through consolidating data, having
easy access for multiple users, having capability to use the software for preventative and
predictive maintenance. Substation equipment data includes: equipment nameplate data,
inspection records, maintenance records,, diagnostic testing, and failure reports. Software can
bring it together, consolidate data, and avoid redundancy.
Substation maintenance records need to be accessed both in the office (on a network server
for multiple users) as well as in the field. Field access through mobile laptop or tablet
computers is needed for inspections and updating maintenance work. Maintenance planning
is enhanced through prioritization by condition, algorithms to find exceptions, advanced
maintenance triggering (such as time, readings, events, or counters), and process
improvement. Criticality or equipment, health, and risks contribute to the priority of
backlogged work. Good documentation of maintenance and risk information to prioritize
planned maintenance work helps achieve the maintenance mission . Future opportunities to
build upon this strong foundation include failure and trouble reporting, capital planning and
asset replacement prioritizations, etc. Software can help save time and money through
improved data access, standardizing maintenance practices, optimizing life of equipment, and
prioritizing scarce resources on the most-needed maintenance.
Kelman Transport X
Roland Weir discussed development of the Kelman Transport X portable DGA device. It was
desired to have rugged & durable equipment, requiring no consumables, easy to use, with
accurate and repeatable results.
The Transport X uses the principle of Photo-Acoustic Spectroscopy (PAS) to determine gas
concentrations in the gas space above oil. It works by pulsing IR radiation at an audible rate,
and detected by sensitive microphones. The IR radiation is produced by a hot wire, sent
through a chopper to pulse the radiation, run through filters to provide a specific wavelength,
then sensed through sensitive microphones.
Alabama Power assisted in development testing of the Transport X. They had a transformer
with 5 ppm acetylene which was repaired and put back in service, then tested two days later.
The Transport X showed 778 ppm, and lab results were 823 ppm. They took the unit out of
service immediately and found an internal winding problem. Kansas City Power & Light
decided to purchase a Transport X and bring DGA testing in-house to save money. They are
performing DGA on 247 transformers, using Transport X to perform this work. Georgia
Power used an on-line version (the Transfix model) to monitor gassing of a problem
transformer producing acetylene and enable it to be kept energized until an outage could be
WECC Substations WG Meeting Minutes, May 2006 Page 9 of 13

arranged. About 100 of the Transport X and 40 of the Transfix are in service in North
America.
Westwing Failure Update
John Lucas from APS discussed the fire at the Westwing 500 & 230 kV yard. The T1
transformer incurred a through-fault on June 14 that did not clear primary protection due to
failure of a Westinghouse auxiliary relay. The breaker failure scheme failed to operate and
the system went to backup protection, subjecting transformer T1 to 20 kA through-faults for
up to 30 seconds. Because this incident caused multiple adjacent breakers to operate, it
distracted attention from possible additional testing to confirm T1 was OK. The transformer
was restored to service after DGA only, and no SFRA or other testing was done.
Then, on July 4, transformer T1 (single phase) caught fire. It spread to three adjacent
transformers because there were no barriers in place. The resulting fire spilled burning oil
into the cable trenches and burned much control wire. To make matters worse, on July 20,
one of three 230/69 kV transformers at Deer Valley substation failed due to a type U bushing
failure and caught fire. After these incidents, system capacity was affected and load had to be
curtailed to maintain stability & reliability.
The current status of Westwing is that all damaged transformers were replaced, additional
spacing between transformers was made, firewalls installed between transformers, and a
quenching fire suppression system was added. They brought in independent industry experts
and formed a local team to evaluate lessons from these incidents. Root cause analysis was
performed by HL Moore, and EPRI solutions was used to evaluate substation practices.
Recommendations from EPRI Solutions included:
• Upgrade protective relaying
• Improve communications
• Implement post-event actions & planning
• Remove Type U bushings
• Use industry standard diagnostics
• Document maintenance basis & discipline
• Prioritize work & backlog
• Evaluate equipment maintenance procedures
• Implement data automation & maintenance intelligence
• Coordinate planning & scheduling
• Develop productivity, planning & scheduling metrics
• Define ownership roles & responsibilities
• Evaluate staffing levels, resource availability, & overtime use
• Perform periodic & on-line monitoring
• Provide training
There were also initiatives added for fire mitigation & fire response as a result of this incident.
A new department, Predictive Maintenance has been formed to be pro-active in preventing
major equipment problems. John also mentioned they have now found many type U bushings
which need replacement
WECC Substations WG Meeting Minutes, May 2006 Page 10 of 13

Transformer Oil Analysis at MWD
Jacky Wong from MWD discussed the Transformer Oil Analysis (TOA) program developed
by Delta-X. They purchased the program in 1998 to manage and analyze transformer and tap
changer DGA results. Their lab, TJH2B, submits lab results in format usable by TOA. Data
is stored in Access MDB format. Software resides on the company server with TOA version
3.3C or on the Internet with TOA version 4. TOA4 is an Internet web-based service available
by subscription. It also has the advantage that no user input is needed since lab results are
submitted directly into the TOA server by the laboratory. Cost for TOA4 is about $1,500.
TOA produces reports and graphs summarizing data submitted through the labs. You can
compare results and see trends easily through the graphs and reports.
Copperweld for theft prevention
Shane Zehnder representing ACA (Alcoa) discussed use of the Copperweld product as a
replacement for copper wire. It has similar current carrying capacity, 8-12% lighter, high
strength, resistant to theft, and provides a reliable connection for grounding applications. It
comes in 30% and 40% conductivity ratings for different applications. Copperweld is used
for pole grounding, transmission line grounding, and substation grounding applications. The
copper is molecularly bonded to the steel. It’s available in reels, coils, or stem packs.
Pricing of copper conductor is about $3.90 per pound, and Copperweld is about $2.96 per
pound. On a per-foot basis, copperweld is about 33% less cost than equivalent copper wire.
Copperweld is theft resistant because there is no scrap value in it, and it is difficult to cut.
Copperweld can be used in direct burial applications, since any corrosion will affect the steel
rather than the copper. Connections can be made with the same devices (Cadweld, crimped,
squeezed) as copper wire.
Discussion of WECC E-mails
• Tom Thee discussed practices for filling SF6 circuit breakers while energized. There
are no known incidents or injuries from adding SF6 to a circuit breaker while it was
energized. Utility practices vary widely and there is no standard practice. Some
utilities vary their practice depending on the manufacturer. Major concern is failure of
a rupture disk while filling. EPRI has proposed a 2007 project to investigate safety of
filling SF6 breakers while energized.
• Battery load testing was discussed. There is an IEEE standard 450 that addresses
battery testing, and other standards (number unknown) for different type batteries.
• Cool-amp conducting lube was discussed. Redding (Bob Sandoval) reported good
results from using this on disconnect switches.
• Some companies have started putting AED’s (defibrillators) on crew vans, and others
have them available on a check-out basis. There was discussion over use, training,
and documentation of the AED’s.
• Discussion over requirements from new regulation NFPA 70E compared to OSHA
1910-269. A quick survey showed the majority of companies require FR clothing and
provide it for employees. LADWP reported a flash burn where the employee was
wearing a FR shirt which provided protection and limited the employee’s flash burns.
APS also experienced several incidents where FR clothing protected employees during
WECC Substations WG Meeting Minutes, May 2006 Page 11 of 13

an incident. WAPA requires employees to wear FR coveralls during exposure
periods. MWD and PG&E are evaluating options to meet requirements.
• Mobile substation manufacturers were discussed. LADWP recently purchased a
mobile and experienced numerous QC issues. SRP purchased a mobile sub made in
Portugal. CSU is in process of purchasing a mobile, but ran into QC, proposal, &
contract issues.
• SF6 gas testing was discussed. Weidman ACTI, TJH2B, & Powertech are the labs
who perform tests. Most companies perform SF6 purity & contaminant testing (at
various intervals).
• Pacificorp asked if others are using the X-ray analysis for determining when to get in
and open up SF6 breakers. PNM has used the X-ray service, and SRP is planning to
use this soon. It was mentioned that another type of diagnostic using frequency
analysis is now available.
• Spare transformer inventory was discussed. Tom Thee will find the voltage matrix
and get it updated.
Miscellaneous
1. PG&E reported problems with closing times (slow) on the Areva SF6 synchronous close
circuit breakers. They found wide variations based on position on sine wave when the
breaker closed.
2. BPA reported problems with condensation inside control cabinets of ABB breakers, and
cabinet seals.
3. PG&E experienced a number of flashovers inside SF6 circuit breakers from ABB, 72 kV
up to 500 kV. Pacificorp, SCE, BPA, and WAPA also had similar problems. CSU has
had problems with ABB breaker mechanisms. BPA has found rusting on springs for ABB
breaker mechanisms.
4. APS had problems with ABB tap changer shaft seals leaking on brand new replacements.
5. BPA asked what manufacturer’s equipment others are using for capacitor and reactor
switching. They reported vibration problems with the Areva live-tank circuit breakers
currently being purchased. BPA has disqualified S&C’s circuit switchers for capacitor or
reactor switching due to other problems.
6. Pacificorp reported numerous problems with the Virginia Transformer (US Transformer)
rewind facility. WAPA also mentioned they have experienced problems during the
ownership transition. CSU asked who performs refurbishing on mobile substations.
7. BPA asked about maintaining disconnect switches. Most utilities don’t do much until the
infrared (IR) uncovers a problem.
8. WAPA reported problems with disconnect switch lubes that collected dirt, then led to
problems.
9. APS asked about asbestos wiring removal. Are others removing asbestos wiring proactively?
10. WAPA asked about grounding of shielded control wiring – is the shield grounded as well
as a separate ground conductor? BPA and IDA ground the shield only.
Service Advisories & Maintenance Problems:
1. ABB/BBC circuit breakers model DL_, EL_, & ED_ in 1976 to 1990 vintage, grading
capacitors may have PCB contamination.
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2. ABB/ITE type GA & GB pneumatic close breakers, failure to trip due to latch assembly.
3. Siemens single phase regulators, MJ-XL controller panel, safety advisory, remote manual
switch can malfunction.
4. GE ML-18H and ML-20 mechanism for Powervac breakers, there is a retrofit kit for
auxiliary switch and linkage.
5. Mitsubishi synchronous close breakers, models 100-SFMT-40SE and 120-SFMT-40SE,
manufactured between Feb 2001 and Oct 2005, have heater elements too close to the
control cabinet wall. Heat radiating from the heater elements can create high heat
concentration on the wire duct, causing a possible malfunction.
6. Powell vacuum breakers with the PowlVac PVS8 operating mechanism, manufactured
from July2004 to March 2006, may fail to trip. Colo Springs had 5 instances of failures
on their system. The fix is to replace the main trip prop.
WECC Substations WG Meeting Minutes, May 2006 Page 13 of 13

Meeting Attendance 5/1 – 5/3, 2006
Name Company Member / Guest
John Lucas Arizona Public Service Member
Brian Clark Arizona Public Service Member
Richard Nicosia Arizona Public Service Member
Craig Lancaster Avista Member
Phil Wanner Basin Elect. Member
Jon Robertson B.C. Hydro Transmission Member
Jerry Almos Bonneville Power Administration Member
Barry Bowman Bonneville Power Administration Member
Abel Periea Bonneville Power Administration Member
Richard Hernandez Bonneville Power Administration Member
Mason Bibles Bonneville Power Administration Guest
Scott Marshall Colorado Springs Utilities Member
L. Dee Curtis Deseret Generation & Trans. Member
Art Harmon Idaho Power Member
Hank Williams Idaho Power Member
John Byars Idaho Power Member
Rick Ruffridge Idaho Power Member
Wes Clark Idaho Power Member
Fernando Gutierrez Imperial Irrigation District Member
Al Minor Imperial Irrigation District Member
Carlos Serrato Imperial Irrigation District Member
Michael Mundo Los Angeles Dept. of Water & Power Member
Jacky Wong Metropolitan Water District Member
Brent Parkin Pacificorp Member
Jack Doney Pacificorp Member
Craig Coddington Pacificorp Member
Tom Thee Pacificorp Member
Tom James Pacific Gas & Elect. Member
Jesse Duffy Portland General Elect. Member
Larry Heath Portland General Elect. Member
Ray Montoya Public Service Co of NM Member
Randy Walls Puget Sound Energy Member
Mark Comer Puget Sound Energy Guest
Gary Veach Puget Sound Energy Guest
Bob Sandoval City of Redding Member
Dave Monday Salt River Project Member
Fred Barker San Diego Gas & Electric Member
Sung Kim Seattle City Light Member
Dix Fulton Seattle City Light Member
Steve Larson Snohomish Public Utility District Member
Chris Zacharia Snohomish Public Utility District Member
Tony Bustamonte Southern Calif. Edison Member
Bryan Fridlund Southern Calif. Edison Member
WECC Substations WG Meeting Minutes, May 2006 Page 14 of 13

Steve Ashbaker WECC Member
Merlin Thompson Western Area Power Admin. Member
Richard Perry Western Area Power Admin. Member
Lee Kenshalo Xcel Energy Member
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