20100616AVU to Staff 79, 89, 92, 97, 102-106.pdf

Avista Corp.
1411 East Mission P.O. Box 3727
Spokane. Washington 99220-0500
Telephone [phone]
Toll Free 800-727-9170
R-ECEJ r1
J.~~'V'STA'
Corp.
June 15,2010
2810 JUH 16 Ali 10= 20
10UTfUT
Idaho Public Utilities Commission
472 W. Washington
Boise, il 83702-5918
Attn: Donald Howell & Krstine Sasser
Deputy Attorneys General
Re: Production Request of the Commission Staff in Case Nos. A VU-E-10-0l and
A VU-G-1O-01
Dear Mr. Howell and Ms. Sasser,
Enclosed are an original and one copy of Avista's responses to IPUC Staffs production requests
in the above referenced docket. Included in this mailng are Avista's responses to production
requests 079,089,092,097, 102 through 106. The production requests are also being provided
in electronic format on the CDs included in this mailing.
If there are any questions regarding the enclosed information, please contact me at (509) 495-
4584 or via e-mail atpaul.kimabll(iavistacorp.com
Sincerely,â?¡,
Paul Kimball
Regulatory Analyst
Enclosures
CC (Email): all paries electronic
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A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-10-01 / AVU-G-10-01
IPUC
Production Request
Staff-079
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/04/2010
Don Kopczyski
Mark Weiss
Engineerng
[phone]
REQUEST:
In Ehrbar's testimony, page 5, lines 4-7, regarding why the Company is proposing an increase of
such magntude in the customer/basic charge, he says "A signficant portion of the Company's
costs are fixed and do not var with customer usage. These costs include distrbution plant and
operating costs to provide reliable service to cutomers." (Emphasis added). He then says this
again on page 32, lines 20-23. Given the recent outage on May 3rd that left 18,000 customers
without power thoughout the Eastern Washington and Nort Idaho serce tertory, please
explain what the Company's crteria is for determining the perormance reliability it provides to
customers. Please include as part of your response an explanation of:
a. How the Company quantifiably measUres its reliabilty perormance.
b. How the Company incorporates the measurement parameters included in the
"IEEE Guide for Electrc Power Distrbution Reliabilty" to make distrbution
plant and operating investment decisions.
c. How the Company uses its Outage Management System (OMS) to determine
what, where and how much improvement is needed.
d. How the Company measures circuit perormance, determnes its tree trmming
cycle, determines outage locations, dispatches crews to trouble areas, and
identifies outages as uncontrollable events.
e. The causes of momentar and sustained outages over the last 5 years.
RESPONSE:
Avista uses several criteria to provide reliable electrc serice to its customer in Washington and
Idaho. Depending on the criteria, specific capital, O&M and maintenance projects/programs are
budgeted for on an anual basis. These projects are prioritized and matched against available
fuding levels to determine which projects/programs are fuded each year. Ths discussion is
mostly about the electrc distrbution system; however some of the reliability information does
include Electrc Transmission impacts.
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Electrc energy is required to be delivered at a ver high degree of availabilty to the customer
within specific voltage tolerances which are defined by ANSI C84.1 - "Amercan National
Standard for Electrc Power Systems and Equipment-Voltage Ratings (60 Her)." Ths National
Standard is often adopted into state law. The distrbution of electrc energy is also limited by the
thermal characteristics of the many pieces of equipment it flows though. To maitai the above
critera, specific types and sizes of equipment are constrcted to serve individual customer(s) or
areas with a lot of individual customers. The specific tyes and sizes of equipment are defined by
additional ANSI standards, ANSI C2 - ''National Electrcal Safety Code", and Electrca and Civil
Engineering calculations/judgment. Ths type of equipment is designed and expected to be long
lived and to withstand the varous physical and environmental conditions of the utilty servce
terrtory. Temperature is one of the environmental conditions. All of ths initial equipment
installation implies a fixed level of costs whether serng a single customer or many customers.
Customer expectations are for very high levels of reliabilty often measured by number of "9' s" of
availabilty. For the Avista serice terrtory over the year 2009, one measure of reliabilty was
measured at 99.963%. Ths translates to a System Average Interrption Duation Index of 193
minutes.
In early 2000, Avista worked with the Washigton Utilities and Transportation Commission
(WC) and other Washington Investor Owned Utilities to develop a program to measure the
reliability of the electrc system with each Utility's serce tertory. These requirements are par
of the Washington Administrative Code 480-100-398 "Electrc servce reliabilty reports", which
are filed anually. Avista filed the first anual report for year-end 2001. Between 2000 and
October of 2005, Avista developed and implemented an Outage Management Tool (OMT or
OMS) based off of the Avista Facilties Management Geographical System (GIS) to improve the
outage response and to provide better and more consistent outage information. The reporting of
the
reliability information is based off of the IEEE Guide for Electrc Power Distrbution Reliabilty
Indices, IEEE P1366. Even though the anual reliability reportg requirements are for
Washington only, Avista reports information on the entie Avista serce terrtory. For the
discussion below, a sustained interrption of electrc servce (outage) is defied to be longer than 5
minutes in duration. An interption of serice that is 5 minutes or less in duration is defined as a
momentar interrption. For more information and detailed explanation of several of the IEEE
Reliabilty Indices, please refer to the Avista Anual Electrc Service Reliabilty Monitorig
Report(s) provided as Staff PR 079-Attachment.
a. How the Company quantifiably measures its reliabilty pedormance - A vista calculates several
of the Indices defined in IEEE P1366 on a monthly/anual basis and analyzes the results
perodically. Each of the individual indices provides a measurement of the overall system or
individual feeder. One of the anual calculations is to determine the level of daily system
average duration that defines what a Major Event Day (MD) is. A MED is outage incidents
that are statistically not normal and represent an event that should be studied separately and
outside of the normal Indices. The outage event on May 3rd 2010 was a Major Event Day for
Avista.
b. How the Company incorporates the measurement parameters included in the "IEEE "Guide for
Electrc Power Distrbution Reliabilty" to make distrbution plant and operating investment
decisions - Over the last two years, the reliabilty information has shown an increase in both
the number of sustained interptions of servce and also the system average lengt of
sustained interptions. As par of the reporting requirements, an area of concern has been
defined and specific plans developed to address the reliabilty concers. Ths area is in the
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.Washington portion of the A vista servce terrtory. Some additional specific feeders in the
Idaho serice terrtory have been identified and capital projects completed in the last two years.
There are additional projects planed in the futue. One specific project was the completion of
the Sagle Substation and associated feeder work to reduce the outages experenced by all of
the
customers on ths long distrbution feeder system. In 2009, A vista had numerous planed
outages to improve the reliability of the Elk City distrbution line out of Grangeville, Idaho.
Work was completed for both Wood Pole Management and also changing the framing on
cerain sections of the feeder that were problematic.
c. How the Company uses its Outage Management System (OMS) to deterine what, where and
how much improvement is needed - The OMS provides a significant amount of data including
location, A vista Offce area, reason/sub-reason for sustained interrption, and the specific
feeder. One of the ver useful tools is to geospatially plot the sustaned outage information on
a GIS area map and look at the customer(s) impacted by the outage(s). These plots are
available in Staff YR _ 079- Attachment. The "reason" causes and any notes from the line
operating personnel responding to the outage are reviewed to deterne what and where to
implement changes to the feeder. Engineering personnel wil tyically meet with the local
operating personnel to discuss the improvements that are planed and then develop the specific
jobs to complete the work. How much improvement is needed is still based on engieerg
judgment and how much improvement actually occurs with work completed on the area.
d. How the Company measures circuit performance, deterines its tree tring cycle,
determnes outage locations, dispatches crews to trouble areas, and identifies outages as
uncontrollable events -
. Individual circuit performance measurements were described above.
A vista has done analysis and has extensive experence in determining the curent tree trmmg
cycle for both the Electrc Transmission and Distrbution System. The industr (utilities,
PUDs, Muncipalities) also reflects varous trmmng cycles from 18 months to five years, with
most utilities utilzing a five (5) year cycle for distrbution line clearance. Trimming cycles are
based on regional tree growt rates and available fuding. Triing cycles provide inspection
and maitenance on a regular basis, and an abilty to identify and remove high-risk trees in a
timely fashion. Site and species are a consideration in all vegetation management programs,
and trees are prued so adequate clearance can be maitained between the tree and the
overhead lines between cycles. The shorter the tring cycle, the less live biomass
(branches) that needs to be removed, and the amount of prug required for each cycle is
signficantly reduced. This assumes the trmming is completed on a regular, established cycle.
Avista's goal is (and Asset Management Modeling has shown) a five (5) year cycle would be
the optimal multiple year work plan for A vista distrbution vegetation management program.
Components of determining the multiple year work plan include tree related outage data last
trm date, and conversations with the local offce operating personneL. The 2010 work plan is
based on curent fuding levels and a projected cost per mile of circuit trmmed (from
historical average anual cost per mile data). The Company's curent vegetation management
plan includes a six (6) plus year cycle..The Transmission Vegetation Management plan relies on a major reclearng activity that is
done on a ten to fifteen year cycle based on vegetation condition obsered during line patrols.
Minor reclearng and hazard tree work or spot work is identified durg anual line patrols
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,
(aerial and ground patrols) and from reports from line servcemen, field personnel and the
System Operator..Avista implemented an Interactive Voice Response system (IV) that provides the star of
the
sustained outage duration and customer location to the OMS. A distrbution dispatcher is
notified of the outage incident(s). As the customer calls come in, they can bundle the incident
together to a common device that may have resulted in the outage. A crew is called and
assigned to the incident to resolve. The assigned crew then responds and makes an assessment
of the outage cause and takes corrective action. If the number of incidents (such as a storm)
becomes very large, additional resources are assigned in Distrbution Dispatch, outages are
prioritized, resources are assigned to provide intial assessment and material needs before a
crew is assigned to that outage area. After each outage event/incident is closed out, the
Dispatcher assign a Reason and Sub-reason cause to the outage from information the
operating personnel provide. The Reason and Sub-reason cause codes provide some abilty to
determine the difference between a "planed" outage versus an "unplaned" outage. See the
Reason and Sub-reason cause code descriptions in Staff_PR-079-Attachment.
e. The causes of momentar and sustaned interrptions over the last 5 years.
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Sustained Interruptions
Customer Minutes Customers Customer Minutes Customers
Reason 2009 2009 (06-09)(06-09)
ANIMAL 6%9%5%7%
COMPANY 1%5%1%4%
EQUIPMENT OH 9%10%10%11%
EQUIPMENT SUB 3%3%3%3%
EQUIPMENT UG 2%1%2%2%
MISCELLANEOUS 0%0%0%0%
PLANNED 15%10%9%8%
POLE FIRE 5%4%8%6%
PUBLIC 5%7%8%9%
TREE 14%10%16%12%
UNDETERMINED 8%17%8%14%
WEATHER 32%25%30%24%
Total 100%100%100%100%
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Momentai;Interruptions
Reason Customers (06-09)
ANIMAL 3%
COMPANY 1%
EQUIPMENT OH 3%
EQUIPMENT SUB 1%
EQUIPMENT UG 1%
MISCELLANEOUS 0%
PLANNED 1%
POLE FIRE 1%
PUBLIC 2%
TREE 1%
UNDETERMINED 66%
WEATHER 19%
Total 100%
Additional cause code reporting is available in Staff_PR_079-Attachment A.
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~~~'V'STAæ
Utilities
2009
Electric Service
Reliability Monitoring
Annual Report
StafLPR_079 Attchment Page 1 of66
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(£ 2009 A vista Corporation. All Right Reserved
Permission of the Copyrght owner is grted to users to copy, download, reproduce, transmit or
distribute any par of this document provided that: (1) the user includes Avista's copyrght notice
on all copies, and (2) the materials are not used in any misleading or inappropriate maner.
Furhermore, no portion of the attached work shall be republished in pnnted or digital form
without the written permission of the Copyrght owner.
2
StafCPR_079 Attchment Page 2 of 66
. CONTENTS
INTRODUCTION ...............................................................................................................1
DATA COLLECTION AND CALCULATION CHANGES ..................................................2
Data Collection............. ..... ......... ...................................... ........ ............................. ........... ......... ............. ..... ....... ......... 2
Interrption Cause Codes ........................................................................................................................................;....3
Customers Experiencing Multiple Interrptions. ..... .......................... ........ ...... .................... .................. ...................... 3
DEFINITIONS ....................................................................................................................4
Reliability Indices....... ... ....... ..... .... ............ ...... .................. ...................................... ..... ............ ..... ...... ........ ............ .... 4
Baseline Reliability Statistics.......................................................................................................................................4
Major Events ................................................................................................................................................................ 6
Customer Complaints................................................................................................................................................... 7
SYSTEM INDiCES.............................................................................................................7
Char 1. i - SAIFI - Sustained Interrptions / Customer..... ............. ....... .............. .................... ..... .............. ................ 8
Chart 1.2 - Sustained Interrptions / Customer Historic Comparson..... .... ........ ................ ............................ ............ 8
SAIFI Linear Trend Line Char............ .... ... ........... ..... ........................ ...... ........ ..... .................... ... .............................. 9
Char 1.4 - Momenta Interrptions/ Customer Historic Comparson ..................................................................... 10
Char 1.5 - SAIDI - Average Outage Time / Customer ............................................................................................. 12
SAIDI Linear Trend Line Char.................................................................................................................................12
Char 1.6 - CAIDI - Average Restoration Time ........................................................................................................ 13.OFFICE INDICES ............................................................................................................14
Char 2. 1 - SAIFI - Sustained Interrptions / Customer ................... .... ................................................ ...... ... ... ......... 14
Char 2.2 - MAIFI Momenta Interrption Events / Customer ................................................................................14
Chart 2.3 - SAIDI - Average Outage Time / Customer ............................................................................................. 15
Char 2.4 - CAIDI - Average Restoration Time ........................................................................................................ 15
AREAS OF CONCERN ...................................................................................................16
Cause Information: ..................... ............. ........ ... .............. .... ..... ....... ....... ............. .......................... ....... ..................... 16
Colville Area Work Plans: .........................................................................................................................................18
A vista System Wide Work Plans: ........................... ............................................................................... ..................... 20
Avista System Wide Vegetation Management Plan: .................................................................................................20
CUSTOMERS EXPERIENCING MULTIPLE INTERRUPTIONS .....................................21
Avista Servce Territory CEMIn Char.......................................................................................................................22
Colville Offce - CEMIn.............................................................................................................................................23
Davenport Offce - CEMIn ..... .......................... .............. ........ ............... ... ............................... ............... .... ................ 24
Deer Park Offce - CEMIn..........................................................................................................................................25
Othello Office - CEMIn ..... ................ .... .................... ......................... ............ .................... .............................. ... ....... 26
Palouse Office - CEMIn ............................................................................................... .............................................. 27
Lewis-Clark Offce - CEMIn......................................................................................................................................28
Spokane Offce - CEMIn........... ................................. ................... .......... ............. ......................... ............................. 29
Sandpoint Office - CEMIn.............................. ............................................................................................................ 30
Kellogg Office - CEMIn ........................................................................................................................ ..... ................ 31
Coeur d' Alene - CEMIn .............................................................................................................................................32
Grangeville Offce - CEMIn .................................................................. .................................. ................................... 33.MONTHLY INDiCES........................................................................................................34
Chart 3.1 - SAIFI - Sustained Interrptions / Customer ............................... ............................................................. 34
StafCPR_079 Attchment Page 30f66
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Char 3.2 - MAIFI Momentar Interrption Events / Customer ................................................................................34
Char 3.3 - SAIDI - Average Outage Time / Customer .............................................................................................35
Char 3.4 - CAIDI - Average Restoration Time ........................................................................................................35
CUSTOMER COMPLAINTS............................................................................................36
Commission Complaints.. .............................................................. ............................................................. ............... 36
Customer Complaints.................................................................................................................................................37
SUSTAINED INTERRUPTION CAUSES.........................................................................39
Table 4.1 - % SAIFI per Cause by Office ..................................................................................................................39
Char 4.1 - % SAIFI per Cause by Offce .................................................................................................................40
Table 4.2 - % SAIDI per Cause by Offce .................................................................................................................41
Char 4.2 - % SAIDI per Cause by Office ................................ .................................................................................42
Table 4.3 - % SAIFI per Cause by Month ................................................................................................................. 43
Char 4.3 - % SAIFI per Cause by Month .................................................................................................................44
Table 4.4 - % SAIDI per Cause by Month .................................................................................................................45
Table 4.4.1 Ave Outage Time ............................................................. .......................................................................46
Char 4.4 - % SAIDI per Cause by Month ................................................................................................................47
MOMENTARY INTERRUPTION CAUSES ......................................................................48
Table 5.1 - % MAIFI per Cause by Office.................................................................................................................48
Table 5.U - % MAII per Cause by Offce (Washington only)...............................................................................49
Char 5.1 - % MAFI per Cause by Office ................................................................................................................ 50
Table 5.2 - % MAFI per Cause by Month ................................................................................................................51
Char 5.2 - % MAIFI per Cause by Month................................................................................................................52
MAJOR EVENT DAY CAUSES.......................................................................................53
Chart 6.1 - % SAII by Cause Code for the Major Event Days ................................................................................ 53
Table 6.1 - % SAIFI by Sub Cause Code for the Major Event Days .................. ...................................................... 54
Table 6.2 - Yearly Sumar of the Major Event Days.............................................................................................55
INTERRUPTION CAUSE CODES...................................................................................56
OFFICE AREAS ..............................................................................................................58
INDICES CALCULATIONS .............................................................................................59
Sustained Interrption ................................................................................................................................................ 59
Momentar Interrption Event................................................................................................................................... 59
SAIFI - System Average Interrption Frequency Index............................................................................................59
MAIFIE - Momenta Average Interrption Event Frequency Index........................................................................59
SAIDI - System Average Interrption Duration Index..............................................................................................59
CAIDI - Customer Average Interrption Duration Index .........................................................................................60
CEMIn - Customers Expenencing Multiple Sustained Interrptions more than n. ................................................... 60
CEMSMIn - Customers experiencing multiple sustained interrption and momentar interrption events. ............. 60
MED - Major Event Day............................................................................................................................................61
NUMBERS OF CUSTOMERS SERVED .........................................................................62
StafCPR_079 Attachment
iv
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Introduction
Washington state investor-owned electnc companies are to provide statements describing their
reliabilty monitoring in an anual report pursuant to WAC 480-100-393 and WAC 480-100-398.
This document reports Avista Utilties' reliabilty metrics for the calendar year 2009. All numbers
in this document are based on system data. The Company's system includes eleven geographical
divisions. Two of these divisions straddle the Washington and Idaho border and commingle
jursdictional customers. A map of Avista's operating area is included in a following section.
WAC 480-100-393 (3)(b) requires the establishment of baseline reliabilty statistics. The
Company's baseline statistics are included in this report.
A vista continues to review its baseline reliabilty statistics in light of operational experience under
this regulatory protocol. A vista may modify its baseline statistics as appropnate and wil update
the Commission accordingly.
Avista added a new section to the 2007 anual report which analyzes the areas where customers
are expenencing multiple sustained outages. This new section provides analysis of a reliability
indice called CEMIn, which implies Customers Expenencing Multiple sustained Interrptions
more than n times.
Avista Utilities
2009 Service and Reliabilty Report Draft 04/16/2009
StafLPR_079 Attachment
1
Page 50f66
. Data Collection and Calculation Changes
WAC 480-100-398 (2) requires the Company to report changes made in data collection or
calculation of reliabilty information after initial baselines are set. This section addresses changes
that the Company has made to data collection.
Data Collection
. Since Avista's Electrc Service Reliability Monitorig and Reporting Plan was filed in
2001, there have been several improvements in the methods used to collect outage data. In
late 2001, centralizing the distribution trouble dispatch and data collection fuction for
Avista's entire service terrtory began. The distribution dispatch offce is located in the
Spokane main complex. At the end of September 2005, 100% of the Company's feeders,
accounting for 100% of the customers, are served from offces that employ central
dispatching.
The data collected for 2009 represents the four full year of outage data collected though the
Outage Management Tool (OMT). For 2009, all data was collected using the "Outage
Management Tool" (OMn based on the Company's Geographic Information System (GIS). The
OMT system automates the logging of restoration times and customer counts.
.A vista did discover a software coding error that has been within the OMT system since 2002 that
wil cause a small increase in the SAII and CAIDI for 2008. Previous years were also evaluated
to determine the overall impact to the A vista baseline statistics and at this time A vista is not
proposing a change to the baseline numbers. The softare error only occured during very specific
outage conditions when a group of customers with an initial outage starting time were "rolled" up
into another group of customers that were determined to be par of the first group outage. The
second group may have had a later outage staing time. When the first group of customer outage
information was rolled up, the original outage staing time was lost and the second group outage
staring time was used for both groups of customers instead of using the fist outage startng time.
The number of customers was counted correctly.
Even as good as the OMT system is at quantifyng the number of customers and duration of the
outage duration, there stil are areas where the data collection is not precise. Determinng the exact
staing time of an outage is dependent on when a customer calls in, how well the A vista
Distrbution Dispatcher determines where the outage is and defies the device that has opened to
remove the faulted section.
As AM AM metering is implemented in the futue and the customer meter provides outage
information to the OMT system though an interface, the SAII and CAII numbers are expected
to increase. This is similar to the above discussion.
Use of the OMT system and GIS data has improved the tracking of the numbers of customers
without power, allowed for better prioritization of the restoration of service and the improved
dispatching of crews..
Avista Utilities
2009 Service and Reliabilty Report Draft 04/16/2009
StafCPR_079 Attchment
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. A vista has reported in the previous anual reports that the completion of the transition to
the OMT system had caused an increase in the variability of the data collected from 2001
to 2007. This Anual Report continues to show that a gradual increase in the SAIFI and
SAII numbers that canot be attbuted to the transition to the OMT system. Review the
chars, on pages 9 and 12 that provide a trend line for SAII and SAIDI historical data.
Continued scrutiny wil be importt over the next year or so to determine if the increase in
SAIFIISAIDI continues, or can be slowed or reversed by reliabilty improvement programs
implemented in 2009 and underway in 20 I O. If it canot be slowed or reversed to examne if this
is drven by other sources or conditions not recognized yet. See SAII Linear Trend Line Chart
later in this document.
Interruption Cause Codes
Cause code information is provided in this report to give readers a better understading of outage
sources. Furher, the Company uses cause information to analyze past outages and, if possible,
reduce the frequency and duration of futue outages.
. The Company made several changes in the classification of outage causes for the
reporting of 2005 outages and subsequent years.
Customers Experiencing Multiple Interruptions
The IEEE Standard 1366P-2003 provides for two methods to analyze data associated with
customers experiencing multiple momenta interrptions and/or sustaied interrptions. Avista's
Outage Management Tool (OMT) and Geographical Information System (GIS) provide the ability
to geospatially associate an outage to individual customer service points. This association allows
for graphically showing Customers Experiencing Multiple sustained Interrptions (CEMln) with
Major Event Day data included onto GIS produced areas. Data can be exported to MS Excel to
also create graphs representing different values of n. 2009 information is provided in the new
section added to the 2007 report after the Areas of Concern Section to sumarize the analysis
A vista performed on the 2009 outage data. The calculation for CEMIn and Customers
Experiencing Multiple Sustained and Momenta Interrptions CEMSMln is provided in the
Indices Section.
Avista Utilties
2009 Service and Reliabilty Report Draft 04/16/2009
StafCPR_079 Attachment
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Definitions
Reliabilty Indices
SAIFI (System Average Interrption Frequency Indices), MAIFI (Momentary Average
Interrption Frequency Indices), SAII (System Average Interrption Duration Indices), and
. CAIDI (Customer Average Interrption Duration Indices) are calculated consistent with industr
stadards as described below. Avista adopts these for puroses of tracking and reporting
reliabilty performance. Furher explanation and definitions are provided in the "Indices
Calculation" section of this report. While these indices are determined using industry standard
methods, it is important to note that differing utilties may use different time intervals for
momenta and sustained outages. Avista defies momenta outages as those lasting five (5)
minutes or less. Sustained outages are those lasting longer than five (5) minutes.
Baseline Reliabilty Statistics
WAC 480-100-393 (3) (b) requires the establishment of baseline reliability statistics. The
Company's 2003 Electrc Service Reliabilty Monitoring and Reporting Plan initially established
Avista's Baseline Reliabilty Statistics. At that time, the Company selected the baseline statistics
as the average of the 2001 though 2003 yearly indices plus two standard deviations (to provide
95% confidence level). In 2006 the Company reviewed the calculation of the baseline statistics in
light of the completion of the transition to the GMT in 2005 and the data collected in 2006.
Calculating the baseline reliability statistics including the 2004 though 2006 data show an
increase in the values, which the Company believes, represents better reporting using GMT. The
Company proposed the latest calculated Baseline Statistic values to reflect the best available data
collection. Because the Company believes that the GMT data collection has affected the SAII
index the most it used the years 2004 to 2006 for the SAIFI Baseline Statistic and the years 2002
to 2006 for the MAI and SAII Indices.
The baseline indices have been adjusted by removing Major Event Days, MED's, as defined in the
following section.
The following table sumarzes the baseline statistics by indices.
2004-2006 Baseline
Indices Average Statistic
~xcmdin2 Mmor Evenæ)(Ave + 2 Stadard Deiations)
SAIFI 1.09 1.44
2002-2006 Baseline
Indices Average Statistic
~xciudi2 Maior Evenæ)(Ave + 2 Stada Deations)
MAIFI
SAIDI
4.52
114
5.82
160
Avista Utilities
2009 Service and Reliabilty Report Draft 04/16/2009
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Additional comparison of the Baseline Indices is provided in the System Indices section of this
report.
A vista is anticipating using the different years in the Baseline Statistics for SAIFI for a few years
until a full five years of data is gathered using the curent Outage Management TooL.
Avista Utilties
2009 Service and Reliability Report Draft 04/16/2009
StafCPR_079 Attachment
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Page 90f66
. Major Events
Major Events and Major Event Days as used in this report are defined per the IEEE Guide for
Electric Power Distribution Reliabilty Indices, IEEE P1366-2003. The following definitions are
taken from this IEEE Guide.
Major Event - Designates an event that exceeds reasonable design and or operation limits
of the electric power system. A Major Event includes at least one Major Event Day (MED).
Major Event Day - A day in which the daily system SAIDI exceeds a theshold value,
T MED. For the puroses of calculating daily system SAIDI, any interrption that spans
multiple calendar days is accrued to the day on which the interrption began. Statistically,
days having a daily system SAII grater than T MED are days on which the energy delivery
system experenced stresses beyond that normally expected (such as severe weather).
Activities that occur on major event days should be separately anlyzed and reported.
The Company wil use the process defined in IEEE P1366 to calculate the theshold value ofTMED
and to determine MED's. All indices wil be reported both including and excluding MED's. The
comparisons of service reliability to the baseline statistics in subsequent years wil be made using
the indices calculated without MED's.
The table below lists the major event days for 2009.
.Major Event
Days
SAlOl
(Customer-
Minutes)
Cause
2009 Major Event Day
Threshold
9.925
No Major Event Days
Additional analysis of the 2009 Major Event Days is not provided in this Anual Report as was
done in previous years staing on Page 53, section Major Event Days Causes.
.
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Page 10 of 66
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Customer Complaints
The Company tracks reliability complaints in two areas, Commission Complaints and Customer
Complaints. Commission Complaints are informal complaints fied with and tracked by the
Commission. Customer Complaints are recorded by our Customer Service Representatives when a
customer is not satisfied with a resolution or explanation of their concern. See the Customer
Complaints section on Page 36 for a summar of results for this year.
System Indices
The charts below show indices for Avista's Washington and Idaho ("system") electrc service
territory by year. Breakdown by division is included later in this report.
The Company continues to use the definition of major events as described above to be consistent
with IEEE Standards. Therefore, the following chars show statistics including the effect of major
events per this definition.
Avista Utilties
2009 Service and Reliabilty Report Draft 04/16/2009
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Page 11 of66
. Chart 1.1 - SAIFI - Sustained Interruptions I Customer
SAl F I I!Excluding Major Events
_Major Events
(/ 2.0
~ 1.8
~ 1.6
ß 1.4
(/ 1.2
6 1.0
g. 0.8
$ 0.6c:
:; 0.4
¡g 0.2.æ
1i 0.0::en 2004 2005 2006 2007 2008 2009 Baseline
Chart 1.2 - Sustained Interruptions I Customer Historic Comparison.Sustained Outage 2009 vs 2004.2008 Average
60000
50000
't 40000.!u
~30000
e!20000Q)
ES 10000II::0:i 0
-10000
-20000
.
SAIFI for 2009 was over the existing baseline established in 2006 and represents the increasing
trend. Using a simple linear regression to establish a trend line, it would look like about a 9.9%
growth in number of customers affected. The R2 coefficient of determination shows a much
stronger correlation to the data than last year. A char of this analysis has been provided just after
this discussion. Major contrbutors to this higher number of customers affected were animals,
planed outages, undetermined, and weather.
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Page 12 of 66
.There were 138,951 customers affected by sustained outages caused by weather in 2009. This
compares to the 2004-2008 average of 83,395 customers.
51,024 customers were affected by sustained outages associated with animal related incidents.
This compares to the 2004-2008 average of28,233 customers. The vast majority of the animal
related reasons were associated with squirrel caused incidents.
Planned maintenance activities and also forced repairs affected 52,838 customers as compared to
the 2004-2008 average of 24,845 customers. Continued maintenance activities associated with the
Company equipment replacement program contrbuted to the increase in this cause and reduced
the Overhead Equipment outage causes.
An increase in the number of Undetermned Causes occured in 2009 as compared to the 2004-
2008 average. 92,117 customers had undetermined causes as compared to the average of 43,835.
A large number of outages were associated with transformer fuses, but there was no known reason
for the fuse to operate. Additional analysis in 2009 along with discussions with local area
personnel could only suspect these maybe animal caused as the common element that is suspected.
No evidence can be contrbuted to these outages.
SAIFI Linear Trend Line Chart
.1.60 .
1.40
1.20
1.00 .
0.80
0.60
0.40
0.20
0.00
2002 2003 2004 2005
Linear Trend for SAIFI without MED's
.. SAIFI W!D MEDs
. Linear (SAIFI W!O MEDs)
2006 2007 2008 2009
.
Avista Utilities
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Page 13 of 66
.Chart 1.3 - MAIFI Momentary Interrption Events / Customer
MAIFI E1Excluding Major Events
_Major Events
6.0
..
Q)5.0E
.9II::U 4.0-
IIcg 3.0a.::..2 2.0E
~
.æ 1.0c
Q)
E0~0.0
r;d-~';~#S-~'ò ~OJ 0~~~~~~.f)~rK~
Chart 1.4 - Momentary Interruptions! Customer Historic Comparison
Momentary Outage 2009 vs 2004-2008 Average
200000
"150000
S(J
:!100000
è:
l!50000Q)
E0-0tn::0
=I
-100000.
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Page 14 of 66
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The 2009 results for MAIFI show a large decrease over 2008 and about the same as 2007 levels.
There was a reduction in weather related momentary outages that canot be explained on weather
conditions alone. There was a corresponding increase in the number of undetermined outages,
which can reflect that weather conditions did cause outages. Distrbution Dispatch continues to
make improvements in correlating the momenta outages with subsequent sustained outages,
which reduces the undetermined causes.
All other categories showed either a slight decrease that would be consistent with previous years.
Avista Utilities
2009 Service and Reliabilty Report Draft 04/16/2009
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Page 150f66
. Chart 1.5 - SAlOl - Average Outage Time I Customer
SAlOl
E1Excluding Major Events
_Major Events
400
L.360Q)
E
.9 320II::280ü-240i:.gê 200.. --
~ E 160:: i!o Q)
i: E 120o .9~~80:: ÜL._40.$E 0-0
Q)d ~~i:
Jg tt ttII::
Cf
~Iött S'tt ~q,tt ~OJ ~~0
tt ~0~
.SAlOl Linear Trend Line Chart
linear Trend for SAlOl without MEOs ..SAIDIW/O MEDs"
Linear(SAIDI W/O MEDs")
250
50
200
150
100
o
2002 2003 2004 2005 2006 2007 2008 2009
.
Avista Utilities
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Page 16 of 66
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Chart 1.6 - CAIDI - Average Restoration Time
IJExcluding Major EventsCAIDI
--c:.- 160E-r.
Q)
.§ 120
CJ::Ü-
Q)80
EF
c:0 40+'
e:.e
CJ
Q)0~
Q)
~
8 Major Events
200
2004 2005 2006 2007 2008 2009 Baseline
Avista Utilities
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Page 17 of 66
.OFFICE Indices
Chart 2.1 - SAIFI - Sustained Interruptions I Customer
~,gl/
Ql/c:
:K2...æ
.E
aic:
Jgl/::(/
.
. Major Events
5.0 ii Excluding Major Events
4.5
4.0
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
0(;0 ,i~0 ~p~ qrf ,i~0 oCbCb ~rf ~O ~e:0 ö~ ':(;0 ~,Cj0e:
'Ò ~ cf :-0~,; t:Cb0 *-~ ~eP O~ q~O t:~ç c.çO ~ d~ ()t¡ () 0~ ° c.f6 ~6'0 V
Chart 2.2 - MAIFI Momentary Interruption Events I Customer
I-
Q)
E
.9rn::Ü
Cìc:o+:a.::l-I-
.æc:ic:
Q)
Eo~
.
.Major Events
.Excluding Major Events14
12
10
8
6
4
2
o
~0 .~0 o?: ~'l .~0 ~Oi ~'l ~o ~0 .~ (;0 øtb,~0 ~~ ~~ ~q, 0~~ ~o r: ~0 ~o'5 b~O ~'l ~.r
o c; ~0 ø0 ,çes ~ ~~ 0 q, ~ c.~ ~Oø.; Q (J rJ. y0 Cj y-
00
1 6
Avista Utilties
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Page 18 ot66
.Chart 2.3 - SAIDI - Average Outage Time I Customer
..
~
~:JÜ-
~ Cñ.- Q)
i- "S
Q) C0)'-co ~..-:Jo
Q)
~
Q)
~
. Major Events
1100 I!Excluding Major Events
1000
900
800
700
600
500
400
300
200
100
o
A.0 .~0 ,.(: _(: .~0 ..~ _(: ~o t:0 .g _~0 øt:0" ~~ ~v a,'(l ~~ Ç)'f ~(l ° iS 0 rf) f.'O
'& ~ ú~ oÅ0~ 0(, tt0.s '¡Rp O~ a,q,O òç ~~ O~~ Qr¡ Q0øG,# o.G (; ~ú00 V
.Chart 2.4 - CAIDI - Average Restoration Time
..(J
E
.9en::Ü-
(JE.-
.- eni- (Jc-o ê~~..-
.9en
~
(J0)~(J
~
.
.MajorEvents
II Excluding Major Events
250
200
150
100
50
o
ø~0 ~~0 d~ ~fl~ ~~0 rtOj ~fl~ ~O ~rj ~~ ,t0 .~0'?
~~ va: 0~ &' ~ .l~. P O~ ~o b~,S~ O~~ v # øø ç ,,~~ a, r¡~ q,~ ~ø'S Q Q 0~ ø g ~d' V
Avista Utilties
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Page 19 of 66
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Areas of Concern
As in previous years, Colville continues to have the lowest reliability of Washington's operating
areas. However, the Colvile area continues to show improvement over previous years as work
plans are implemented. Colvile was judged lowest based on its performance in the yearly indices
for SAII, SAII, CAIDI, and MAIF!. Within the Colvile area, six feeders were identified as the
areas of concern for 2009. These feeders are Gifford 34F1, Gifford 34F2, Colvile 34F1, Colvile
12F4, Valley 12F3 and Valley 12Fl. For this report, these same six feeders are identified as the
areas of concern for 2009.
Cause Information:
Generally rual areas have a greater number of outages per customer. Colvile is a predominately
rual and forested area. There are approximately 2342 miles of distribution line exposed to
weather, underground cable failures and tree problems. Unlike most of the Company's system,
lines in this area are built on the narow, cross-countr rights-of-way, tyical of PUD constrction
practices prior to A vista acquirg the system. These conditions make patrollng, tree trimming,
right of way clearng and other maintenance difficult. When cost effective, Avista moves sections
of these overhead lines to road rights of way and/or converts them to underground.
Furher, when outages occur in rual areas, the time required to repair daage is longer. More time
is required for first responders to arve and assess the daage and more time is required for the
crew to reach the site. Often the damage is off road and additional time is required to transport
materials and equipment to the site.
Listed below is a summary of the specific cause data for each feeder. This is a compilation of data
from the Avista Outage Management Tool and the reportng from our local servcemen to
Distrbution Dispatch. Data from the reportng system is shown as a percentage of total customer-
outages, (SAII) for that feeder.
Snow loading on green healthy trees growing beyond the rights-of-way often causes them to bend
or break and contact distribution lines. These trees are not cut as par of our vegetation
management program because they are outside our right of way and are considered healthy
marketable timber.
Gifford 34F1
. 19.1 % Weather: snow, wind and lightning storms
. 9.5% Equipment
. 0.0% Pole fies
. 2.4% Trees
. 19.1% Planned outages
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Page 20 of 66
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.
Colvile 34F1
. 35.7% Weather; snow, wind and lightning storms
. 11.4% Equipment
. 2.0% Pole fires
. 14.3% Trees
. 9.1 % Planned outages
Chewelah 12F3
. 33.6% Weather: snow, wind and lightning storms
. 5.2% Equipment
. 3.5% Trees
. 15.5% Planed outages
. 7.8% Animal: birds or squirels
Gifford 34F2
. 19.7% Weather: Wind, snow, and lightning storms
. 9.2% Equipment
. 1.3% Pole Fires
. 10.5% Trees
. 11.8% Planed outages
. 14.5% Animal: birds or squirrels
Valley 12Ft
. 25.8% Weather: snow, wind and lightng storms
. 10.3% Equipment
. 11.3% Trees
. 7.2% Public
. 7.2% Planed outages
. 4.1 % Animal: birds or squirrels
Valley 12F3
. 17.7% Weather: wind and lightning storms
. 5.9% Equipment
. 5.9% Trees
. 23.5% Public
. 23.5% Planed outages
. 0.0% Animal: birds or squirrels
Avista Utilities
2009 Service and Reliability Report Draft 04/16/2009
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Page 21 of 66
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Colville Area Work Plans:
The improvement work that has been accomplished or planed for each feeder is listed below.
The Company's reliability workig group is continuing to study these feeders to develop
additional work plans. Each of the identified feeders also had planed outages that correspond to
the maintenance and replacement activities in the area.
Gifford 34Fl
. 10,300' ofUR cable was replaced in 2009, and 12,850' ofUR cable is planed for
replacement in 2010.
. A reliabilty improvement project is scheduled for 2010 in the Pleasant Valley area of this
feeder to replace (42) 1940 class poles with new poles and replace approximately 2.2 miles
of I-phase #6A, #6CW, and #9 1/2D wire (all in poor shape) with 2-phases of #2ACSR
wie.
. Vegetation Management completed tree trmmng of698 trms and 522 tree removals in
2009. No work planned for 2010.
Colvile 34Fl
. 12,350 ofUR cable was replaced in 2009. None is scheduled to be replaced on this
feeder in 2010
. A capital improvement project was completed in 2009 to replace 2.2 miles of 3-phase #6
Crapo wire in poor condition in a difficult access area with 3-phases or UR cable.
. A reliabilty improvement project is planed for 2010 to perform an RF surey of the tr
of this feeder and pedorm follow-up work to address issues that are found.
. Vegetation Management completed 6 tree trms and 713 tree removals in 2009. No work
planed for 2010.
Chewelah 12F3
. 7700' ofUR cable was replaced in 2009, and 5200' ofUR cable is planed for
replacement in 2010.
. A reliability improvement project was completed in 2009 to split the Chewelah 12F3 into
two feeders (Chewelah 12F3 and Chewelah 12F4). Also, another reliabilty project was
completed to convert 2- miles of I-phase overhead line with bad access with 2-phases of
UR.
. Late December 2009 saw the completion of the new Chewelah 12F4 feeder, which split the
existing 12F3 into two par. The origial 12F3 feeder was almost 66 miles in circuit miles
and is now about 26 circuit miles. 12F4 wil be about 40 circuit miles.
Gifford 34F2
. 2775' ofUR cable was replaced in 2009, and 8510' ofUR cable is planed for
replacement in 2010.
. A reliabilty improvement project is planed for 2010 to convert 3.5 miles of3-phase
overhead line to UR in the Twin Lakes area near Inchelium.
Valley 12F1
. No UR cable was replaced in 2009, but 300' ofUR cable is planed for replacement in
2010.
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Page 22 of 66
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.
. A reliability improvement project was completed in 2009 to convert 1.9 miles of I-phase
overhead line to UR in the Hesseltine Rd. area.
. Another reliabilty improvement project is planed for 20 I 0 to convert 3.2 miles of 2-
phase overhead line to I-phase UR in the Jepsen Rd area.
Valley 12F3
. 1300' ofUR cable was replaced in 2009, and 700' ofUR cable is planed for
replacement in 2010.
. Vegetation Management completed 749 tree tris and 293 tree removals in 2009. A small
amount of work is planed for 2010.
Avista tyically uses several different protective devices on its feeders to isolate faulted or
overloaded sections and also continue to serve the remaining customers. Generally, two different
protection schemes are used to either "save" the lateral fuse or "blow" the lateral fuse by using or
not using the instantaneous over curent trp. Depending on the feeder, number of customers, tyes
of faults, (temporary or permanent), customer tye, time of year, etc. both of these schemes may
be used on an individual feeder at different times at the discretion of the field personneL. With the
better data and cause code collection that GMT provides and the customer growth on some of the
Colvile feeders, changes to the tye of scheme used has been reviewed. Listed below are major
reliabilty projects specifically identified by feeder. Three of these are in the State ofIdaho.
Feeder Decisions/ basis 2010 2011 and
beyond
Gifford 34Fl Reliability improvements Budgeted Planed
Gifford 34 F2 Reliabilty improvements Budgeted Planned
Colville 34Fl Reliabilty improvements Budgeted Planed
Valley 12FI This feeder was first identified in mid Budgeted Planed
2006 as having areas that would be of
concern. Capital dollars have been
budgeted in 2010 to identify and
implement some reliabilty
improvement.
Valley 12F3 Fusing protection was revised and Planned
updated. Additional reliability
improvements maybe budgeted in
futue years.
Wallace 542 New*Reliability Improvement Budgeted
Gragevile 1273*Engieerig is on going along with Budgeted Planed
Wood Pole Management related work
to identify reliabilty improvements
for this feeder.
Saint Maries 633*Reliabilty Improvement Budgeted Planned
* Not included as an area of concern in this report.
Avista Utilties
2009 Service and Reliability Report Draft 04/16/2009
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Page 23 of 66
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Avista System Wide Work Plans:
A vista develops a detailed annual budget for various improvements to the facilities it owns and
operates. For 2009, three reliability feeder projects (one has been deferred to 2010) were
completed and described above. The reliabilty improvement should show up over the next couple
of years. Additionally Asset Management has developed some specific projects that are expected
to improve reliabilty on several feeders system wide. These projects are summarzed in the table
below.
Porcelain cutout replacements were completed at the end of 2009.
During 2009, Avista looked at the possibilty of performng extensive constrction and
rehabiltation of the Ninth and Central 12F4 feeder in Spokane. This included reconductoring
specific sections ofline for loss improvement, changig transformers that were older than 1983,
replacing many long seconda districts, and replacing many wood poles. Reliability in 2009 was
degraded due to the many planned outages, however only two non planed outages have been
reported in early 2010. Additional review wil be done for the year end 2010.
Material records show that some wildlife guards were installed on new distrbution transformers
installations starting in the mid 1980's. With the recognition of increases in animal caused
outages, new materials and improvements have been made in the constrction standards for new
distribution transformer installations to reduce these tyes of outages. Initial indications show that
the outage reduction on a feeder after wildlife guards are installed is significant.
2009 was the sta of the multiyear wildlife guard installation program to reduce the squirel and
bird related outages on approximately sixty feeders in Washington and Idaho. Most of the wildlife
guards were installed with a hot stick on existing transformers that do not have an existing wildlife
guard.
Avista installed a total of 4534 wildlife guards on 20 feeders in 2009. There were 2130 wildlife
guards installed in Idao on 9 feeders and 2404 wildlife guards installed in Washington on 11
feeders. One feeder (Orin l2F3) in the Colvile area had wildlife guards installed last year.
A vista deferred plans to install wildlife guards on additional feeders in Washington for 2010 due
to unfavorable pro-forma rate treatment of the program. Avista wil continue with plans to install
wildlife guards in the State ofIdaho. 9 feeders are planed to have wildlife guards installed.
Asset Management in conjunction with the Wood Pole Management Program stubbed or replaced
numerous poles and additionally replaced numerous pole top transformers and associated
cutouts/aresters.
Avista System Wide Vegetation Management Plan:
A vista has an anual vegetation management plan and budget to accomplish the plan. The budget
is allocated into distribution, transmission, admistration, and gas line reclearg.
Distrbution
Our curent plan for Avista's distribution system is managed by Asplundh Tree Expert Co. Every
distrbution circuit is scheduled to be line clearance prued on a regular maintenance cycle of four
year urban and seven years rual. Other distrbution vegetation management activities include
hazard tree patrol and herbicide application.Avista Utilties 20
2009 Service and Reliability Report Draft 04/16/2009StafCPR_079 Attachment Page 24 of 66
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.
Transmission
The transmission system is managed by Avista's forester. All 230 kV lines are patrolled anually
for hazard trees and other issues, and mitigation is done in that same year. Approximately one
third of 115 kV transmission system is patrolled annually for hazard tree identification, and
assessment of right of way clearing needs. Right of way clearg maintenance is scheduled and
performed approximately every ten to fifteen years (for each line). Interim spot work is done as
identified and needed. Engineering specifications for varous voltages, line configuations are
followed when clearing the right of way. Curently, the work is bid to a variety of contractors.
Customers Experiencing Multiple Interruptions
A vista has used the data from the OMT system integrated with the GIS system to geospatially
display reliabilty data for specific conditions. The specific conditions imply looking at the
number of sustained interrptions for each service point (meter point). This would be similar to
the SAIFI indice, but would be related to a certin number of sustained interrptions. A vista
includes all sustained interrptions including those classified under Major Event Days. This
provides a view of what each customer on a specific feeder experiences on an anual basis.
Momentar Interrptions are not included in the CEMln indice, because of the lack of indication
on many of the rual feeder reclosers.
The first char below provides a view of the percentage of customers served from the A vista
system that have sustained interrptions. 65 % of A vista customers had 1 or fewer sustained
interrptions and 5.4% of Avista customers had 6 or more sustained interrptions durg 2009.
The remaining geographic plots show the sustained interrptions by color designation according to
the legend on each plot for each office area. Note the office area is designated as the area in white
for each plot and that there is overlap between adjacent offce area plots. The adjacent offce areas
are shown in light yellow.
The plots provide a quick visual indication of varng sustained interrptions, but significant
additional analysis is required to determine underlying cause(s) of the interrptions and potential
mitigation.
Avista Utilities
2009 Service and Reliabilty Report Draft 04/16/2009
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Page 25 of 66
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.
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66
. Colville Office - CEMln
+' i... _.- .. ", .".,-'"- t:
,
2009 Incident Distribution
Colvine Offce
l.Inciat~ PoinNu of.in
lJ
~:i. -
HO
. n.211
. 21--
TopTen8=
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Avista Utìlìtíes
2009 Service and Reliabilty Report Draft 04/16/2009
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23
Page 27 of 66
.Davenport Offce - CEMln
.
~'~..'\.
;7"..~'
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Avista Utilities
2009 Service and Relìability Report Draft 04/16/2009
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Page 28 of 66
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Deer Park Office - CEMln
"..'~\. 1:4- ~- ~.~ -~ j L),._"""..~..-. T'~""~.._,_ "~'
.t" ...,..t, \" ., to"", ; ClMalt,aoi
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25
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34Avista Utilities
2009 Service and Reliability Report Draft 04/16/2009
StafCPR_079 Attachment Page 38 of 66
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35Avista Utilties
2009 Service and Reliability Report Draft 04/16/2009
StafCPR_079 Attachment Page 39 of 66
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n
o
w

w
h
a
t

A

v
i
s
t
a

i
s

d
o
i
n
g

t
o
Sp
i
r
i
t

1
2
F
1
en
s
u
r
e

r
e
l
i
a
b
l
e

s
e
r
v
i
c
e
.

O
n
e

o
f

th
e

r
e
p
s

t
o
l
d

h
i
m

t
o

b
u
y

a
ge
n
e
r
a
t
o
r
.

P
l
e
a
s
e

s
u
p
p
l
y

i
n
f
o
r
m
a
t
i
o
n

o
n

c
i
r
c
u
i
t
,

o
u
t
a
g
e

c
a
u
s
e
s
,
nu
m
b
e
r

o
f

c
u
s
t
o
m
e
r
s

a
f
f
e
c
t
e
d
,

S
A
I
D
I
/
S
A
I
F
I
,

C
o
n
d
i
t
i
o
n

o
f
ci
r
c
u
i
t
,

a
n
y

i
m
p
r
o
v
e
m
e
n
t

p
r
o
j
e
c
t
s
,

r
e
p
a
i
r

h
i
s
t
o
r
y
.
Sp
r
i
n
g
d
a
l
e
,

W

A
Cu
s
t
o
m
e
r

h
a
s

h
a
d

s
e
v
e
r
a
l

p
o
w
e
r

s
u
r
g
e
s
,

b
r
o
w
n

o
u
t
s
,

l
o
w
Av
i
s
t
a

r
e
s
p
o
n
d
e
d

t
o

c
u
s
t
o
m
e
r

1
1
/
2
/
2
0
0
9

C
o
n
s
t
r
u
c
t
i
o
n

o
f
f
i
c
e

i
s
vo
l
t
a
g
e
,

t
r
p
s

a
n
d

r
e
s
e
t
s

i
n

h
i
s

a
r
e
a

a
n
d

h
a
s

b
e
e
n

t
r
i
n
g

t
o

g
e
t

t
h
e
in
v
e
s
t
i
g
a
t
i
n
g

a
n
d

w
i
l

p
u
t

r
e
p
a
i
r
s

i
n

p
l
a
c
e

-

i
s

t
o

b
e

s
c
h
e
d
u
l
e
d
.
Va
l
l
e
y

1
2
F
1
co
m
p
a
n
y

t
o

f
i
x

t
h
e

p
r
o
b
l
e
m

s
i
n
c
e

a
b
o
u
t

A
u
g
u
s
t

2
0
0
9
.

S
h
e

c
a
l
l
s
re
p
a
i
r

a
n
d

t
h
e

c
o
m
p
a
n
y

a
s
k
s

i
f

s
h
e

h
a
s

p
o
w
e
r

a
n
d

w
h
e
n

s
h
e

s
a
y
s
ye
s
,

t
h
e
y

s
a
y

t
h
e
y

w
i
l

lo
o
k

i
n
t
o

i
t
.

H
o
w
e
v
e
r
,

t
h
e

c
o
m
p
a
n
y

h
a
s
no
t

f
i
x
e
d

t
h
e

p
r
o
b
l
e
m
,

n
o
r

h
a
v
e

t
h
e
y

t
o
l
d

h
e
r

w
h
e
n

t
h
e

p
r
o
b
l
e
m
wi
l

b
e

f
i
x
e
d
.
Av
i
s
t
a

U
t
i
l
t
i
e
s
20
0
9

S
e
r
v
i
c
e

a
n
d

R
e
l
i
a
b
i
l
t
y

R
e
p
o
r
t

D
r
a
f
t

0
4
/
1
6
/
2
0
0
9
36
St
a
f
C
P
R
_
0
7
9

A
t
t
c
h
m
e
n
t
Pa
g
e

40

o
f

66
.
.
.
Cu
s
t
o
m
e
r

C
o
m
p
l
a
i
n
t
s
Th
e

f
o
l
l
o
w
i
n
g

i
s

a

l
i
s
t

o
f

c
o
m
p
l
a
i
n
t
s

m
a
d
e

t
o

o
u
r

C
u
s
t
o
m
e
r

S
e
r
v
i
c
e

R
e
p
r
e
s
e
n
t
a
t
i
v
e
s
.
Cu
s
t
o
m
e
r

I
Co
m
p
l
a
i
n
t
Re
s
o
l
u
t
i
o
n
Fe
e
d
e
r
Sp
o
k
a
n
e
,

W
A
Cu
s
t
o
m
e
r

i
s

c
o
n
c
e
r
n
e
d

a
b
o
u
t

t
h
e

f
r
e
q
u
e
n
t

s
h
o
r
t

p
o
w
e
r

o
u
t
a
g
e
s
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Fr
a
n
c
i
s

&

C
e
d
a
r

1
2
F
4
ov
e
r

t
h
e

p
a
s
t
.

S
a
y
s

i
t

i
s

i
m
p
a
c
t
i
n
g

h
i
s

e
l
e
c
t
r
o
n
i
c

e
q
u
i
p
m
e
n
t
.
Li
k
e

t
o

k
n
o
w

i
f

t
h
e
r
e

i
s

s
o
m
e
t
h
i
n
g

t
h
a
t

c
a
n

b
e

d
o
n
e
.
Le
w
i
s
t
o
n
,

I
D
Lo
s
t

E
q
u
i
p
m
e
n
t

D
u
e

t
o

O
u
t
a
g
e
Cl
a
i
m

F
i
l
e
d

6
/
2
2
/
0
9
.

C
l
a
i
m

r
e
j
e
c
t
e
d
,

r
e
p
a
i
r
s

m
a
d
e

t
o

s
e
r
v
i
c
e
.
Te
n
t
h

&

S
t
e
w
a
r

1
2
5
4
Sp
o
k
a
e

V
a
l
l
e
y
,

W
A
Cu
s
t
o
m
e
r

c
a
l
l
e
d

t
o

c
o
m
p
l
a
i
n

a
b
o
u
t

r
e
c
e
n
t

o
u
t
a
g
e
s
,

f
e
e
l
s

l
i
k
e

s
h
e
Cu
s
t
o
m
e
r

d
i
d

n
o
t

w
a
n
t

ca
l
l

b
a
c
k

j
u
s
t

w
a
n
t
e
d

t
o

h
a
v
e

c
o
m
p
l
a
i
n
t

o
n
Be
a
c
o
n

1
2
F
l
li
v
e
s

i
n

3
r
d

w
o
r
l
d

c
o
u
n
t
r

a
n
d

h
i
g
h
e
r

t
h
e

r
a
t
e
s

g
o

t
h
e

w
o
r
s
e

t
h
e
fi
e
.

7
/
9
/
2
0
0
9
se
r
v
i
c
e
.

W
a
n
t
e
d

t
o

f
i
l
e

a

f
o
r
m
a
l

c
o
m
p
l
a
i
n
t

a
n
d

b
e
l
i
e
v
e
s

w
e
ne
e
d

t
o

d
o

s
o
m
e
t
h
i
n
g

a
b
o
u
t

t
h
i
s
.

L
a
s
t

w
e
e
k

o
u
t

f
o
r

5

h
o
u
r
s

a
n
d
th
e
n

o
f
f

a
n
d

o
n

f
o
r

n
e
x
t

f
e
w

d
a
y
s
.
No

L
o
c
a
t
i
o
n

G
i
v
e
n
Cu
s
t
o
m
e
r

f
e
e
l
s

s
h
o
u
l
d

n
o
t

b
e

o
u
t

f
o
r

t
h
i
s

l
o
n
g

o
f

t
i
m
e

s
i
n
c
e
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
we
n
t

t
o

u
n
d
e
r
g
r
o
u
n
d
.

N
o

o
n
e

e
l
s
e

o
n

s
t
r
e
e
t

i
s

o
u
t
.
Ra
t
h
d
r
m
,

I
D
Cu
s
t
o
m
e
r

v
e
r
y

u
n
h
a
p
p
y

p
o
w
e
r

k
e
e
p
s

g
o
i
n
g

o
u
t

i
n

R
a
t
h
d
r
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Ra
t
h
d
r
m

2
3
1
Ar
e
a
.

S
a
y
s

s
h
e

w
a
n
t
s

t
o

t
a
e

m
o
n
e
y

o
f
f

o
n

w
h
a
t

s
h
e

p
a
y
s

d
u
e

t
o
la
c
k

o
f

q
u
a
l
i
t
y

o
f

s
e
r
v
i
c
e
.
Ha
r
r
i
s
o
n
,

I
D
Cu
s
t
o
m
e
r

c
a
l
l
e
d

f
o
r

e
s
t
i
m
a
t
e
d

r
e
s
t
o
r
a
t
i
o
n

o
n

o
u
t
a
g
e
,

t
h
o
u
g
h
t
Su
p
e
r
v
i
s
o
r

n
o
t
i
f
i
e
d

o
f

c
o
m
m
e
n
t
.

N
o

a
c
t
i
o
n

o
r

c
a
l
l
b
a
c
k

r
e
q
u
i
r
e
d
.
Og
a
r
a

6
1
1
wa
s

p
l
a
n
n
e
d

o
u
t
a
g
e

w
e

d
e
c
i
d
e
d

t
o

d
o

e
a
r
l
y
.

A
d
v
i
s
e
d

c
u
s
t
o
m
e
r
9/
0
3
/
2
0
0
9
ou
t
a
g
e

w
a
s

u
n
p
l
a
n
n
e
d

a
n
d

g
a
v
e

e
s
t
i
m
a
t
e
d

r
e
s
t
o
r
a
t
i
o
n

t
i
m
e
.
Cu
s
t
o
m
e
r

s
a
i
d

t
h
a
t

w
e

s
h
o
u
l
d

n
o
t

g
o

a
h
e
a
d

w
i
t
h

p
l
a
n
n
e
d

o
u
t
a
g
e
si
n
c
e

h
a
s

b
e
e
n

o
u
t

o
f

p
o
w
e
r

s
i
n
c
e

1

:
3
0
A
M
.

A
d
v
i
s
e
d

c
u
s
t
o
m
e
r
ou
t
a
g
e

w
a
s

n
o
t

r
e
p
o
r
t
e
d

u
n
t
i
l

7
:
1
5
A
M
.

B
e
l
i
e
v
e
s

A
v
i
s
t
a

s
h
o
u
l
d
ha
v
e

e
q
u
i
p
m
e
n
t

t
h
a
t

t
e
l
l
s

u
s

of

po
w
e
r

o
u
t
a
g
e
s
.
Ca
t
a
l
d
o
,

I
D
Cu
s
t
o
m
e
r

w
a
s
n
'
t

t
o
l
d

a
b
o
u
t

p
l
a
n
n
e
d

o
u
t
a
g
e
.

S
u
g
g
e
s
t
s

n
o
t
i
f
y
i
n
g
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Mi
s
s
i
o
n

4
3
1
cu
s
t
o
m
e
r
s

f
o
r

p
l
a
n
n
e
d

o
u
t
a
g
e
s
.
Av
i
s
t
a

U
t
i
l
t
i
e
s
20
0
9

S
e
r
v
i
c
e

a
n
d

R
e
l
i
a
b
i
l
t
y

R
e
p
o
r
t

D
r
a
f
t

0
4
/
1
6
/
2
0
0
9
37
St
a
f
C
P
R
_
0
7
9

A
t
t
c
h
m
e
n
t
Pa
g
e

41

o
f

66
.
.
.
Li
n
c
o
l
n

C
o
u
n
t
y

W

A
Cu
s
t
o
m
e
r

w
a
s

p
a
r
t

o
f

e
x
t
e
n
d
e
d

o
u
t
a
g
e
s
.

B
e
l
i
e
v
e
s

i
f

A
v
i
s
t
a
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Un
k
n
o
w
n

F
e
e
d
e
r
wo
u
l
d

h
a
v
e

p
e
r
f
o
r
m
e
d

m
a
i
n
t
e
n
a
n
c
e

d
u
r
n
g

s
u
m
m
e
r

t
h
a
t

o
u
t
a
g
e
s
wo
u
l
d

n
o
t

h
a
v
e

o
c
c
u
r
e
d
.

S
a
y
s

m
a
i
n
t
e
n
a
n
c
e

s
h
o
u
l
d

b
e

p
r
i
o
r
i
t
y
ov
e
r

m
g
m
t

c
o
m
p
e
n
s
a
t
i
o
n
.
No

L
o
c
a
t
i
o
n
Cu
s
t
o
m
e
r

w
o
u
l
d

l
i
k
e

r
e
b
a
t
e

o
n

a
l
l

t
h
e

t
i
m
e
s

s
e
r
v
i
c
e

h
a
s

b
e
e
n
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
In
f
o
r
m
a
t
i
o
n
di
s
r
u
p
t
e
d
Sp
o
k
a
n
e

V
a
l
l
e
y
,

W
A
Cu
s
t
o
m
e
r

C
o
m
p
l
a
i
n
t

a
b
o
u
t

r
a
t
e
s
,

e
x
e
c
u
t
i
v
e

p
a
y

a
n
d

r
e
p
e
a
t
e
d
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Li
b
e
r
t
y

L
a
k
e

1
2
F
2
Po
w
e
r

O
u
t
a
g
e
s
.
Li
b
e
r
t

L
a
k
e
,

W

A
Cu
s
t
o
m
e
r

w
a
n
t
e
d

u
s

t
o

c
h
a
n
g
e

s
c
h
e
d
u
l
e
d

o
u
t
a
g
e

b
e
c
a
u
s
e

o
f
Ad
v
i
s
e
d

c
u
s
t
o
m
e
r

c
o
u
l
d

n
o
t

c
h
a
n
g
e

o
u
t
a
g
e

t
i
m
e
.
Li
b
e
r
t

L
a
k
e

1
2
F
3
ho
l
i
d
a
y

a
n
d

e
v
e
r
y
o
n
e

h
o
m
e
.

N
o
t
e
d

t
h
a
t

n
e
x
t

t
i
m
e

t
o

s
c
h
e
d
u
l
e
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
fo
r

n
o
n
-
h
o
l
i
d
a
y

a
n
d

w
a
n
t
e
d

f
r
u
s
t
r
a
t
i
o
n
s

n
o
t
e
d
.
Ed
w
a
l
l
,

W
A
Cu
s
t
o
m
e
r

u
p
s
e
t

a
b
o
u
t

s
c
h
e
d
u
l
e
d

o
u
t
a
g
e

a
n
d

n
o
t

p
e
r
s
o
n
a
l
l
y
Ar
e
a

M
a
n
a
g
e
r

c
o
n
t
a
c
t
e
d

c
u
s
t
o
m
e
r

6
/
2
5
/
2
0
0
9
.

N
o

R
e
s
o
l
u
t
i
o
n
Re
a
r
d
a
n

1
2
F
2
no
t
i
f
i
e
d
.
Do
c
u
m
e
n
t
e
d
.
Sp
o
k
a
e
,

W
A
Cu
s
t
o
m
e
r

w
a
n
t
s

t
o

k
n
o
w

w
h
y

c
l
o
c
k
s

w
e
r
e

f
l
a
s
h
i
n
g

l
a
s
t

n
i
g
h
t
.
No

o
u
t
a
g
e

r
e
p
o
r
t
e
d

i
n

h
i
s

a
r
e
a

o
n

1
0
/
6
/
2
0
0
9
.

S
u
g
g
e
s
t
e
d

t
o

c
u
s
t
o
m
e
r
Mi
l
w
o
o
d

1
2
F
2
Sa
y
s

t
h
i
s

h
a
p
p
e
n
s

f
r
e
q
u
e
n
t
l
y
pr
o
b
a
b
l
y

l
i
m
b
s

o
n

l
i
n
e
,

s
m
a
l
l

a
n
i
m
a
l

e
t
c
.

C
u
s
t
o
m
e
r

n
o
t

c
o
m
p
l
e
t
e
l
y
sa
t
i
s
f
i
e
d
.

N
o

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Wi
l
b
u
r
,

W
A
1/
1
5
/
0
9
C
u
s
t
o
m
e
r

n
o
t

h
a
p
p
y

w
i
t
h

t
h
e

s
e
r
v
i
c
e
.

P
o
w
e
r

k
e
e
p
s

g
o
i
n
g
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Wi
l
b
u
r

1
2
F
2
on

a
n
d

o
f
f

s
t
e
a
d
i
l
y

f
o
r

t
h
e

l
a
s
t

1
2

h
o
u
r
.
11
1
6
/
0
9

C
u
s
t
o
m
e
r

u
p
s
e
t

h
e

k
e
e
p
s

g
e
t
t
i
n
g

s
a
m
e

u
p
d
a
t
e

w
h
e
n

t
h
e
se
r
v
i
c
e

s
h
o
u
l
d

b
e

b
a
c
k

u
p
(
1
I
l

7
/
0
9
)
.

S
t
a
t
e
s

A
v
i
s
t
a

s
h
o
u
l
d

h
i
r
e
mo
r
e

c
r
e
w
s

t
o

h
e
l
p

i
n

t
h
i
s

o
u
t
a
g
e
.
Ed
w
a
l
l
,

W
A
Cu
s
t
o
m
e
r

u
p
s
e
t

n
o
t

n
o
t
i
f
i
e
d

a
b
o
u
t

p
o
w
e
r

o
u
t
a
g
e
.
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Re
a
r
d
a

1
2
F
2
Ke
t
t
l
e

F
a
l
l
s
,

W

A
Cu
s
t
o
m
e
r

n
o
t
i
f
i
e
d

u
s

t
h
a
t

w
e

s
h
u
t

o
f
f

p
o
w
e
r

t
o

t
h
e

t
r
l
e
r

p
a
r
k
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Gr
e
e
n
w
o
o
d

1
2
F
l
wh
i
l
e

w
e

c
h
a
n
g
e
d

t
r
a
n
s
f
o
r
m
e
r
.

U
p
s
e
t

w
e

d
i
d

n
o
t

n
o
t
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f
y

t
h
e
m
.
Ke
t
t
l
e

F
a
l
l
s
,

W

A
Cu
s
t
o
m
e
r

u
p
s
e
t

a
b
o
u
t

p
l
a
n
e
d

o
u
t
a
g
e
.

K
n
e
w

a
b
o
u
t

o
u
t
a
g
e

b
u
t
No

R
e
s
o
l
u
t
i
o
n

D
o
c
u
m
e
n
t
e
d
.
Sp
i
r
i
t

1
2
F
l
Av
i
s
t
a

i
s

l
a
t
e

f
o
r

t
u
i
n
g

p
o
w
e
r

b
a
c
k

o
n
.

S
t
a
t
e
d

w
e

n
e
e
d

t
o

w
o
r
k
at

n
i
g
h
t

b
e
c
a
u
s
e

o
f

hu
g
e

i
n
c
o
n
v
e
n
i
e
n
c
e
.
Av
i
s
t
a

U
t
i
l
t
i
e
s
20
0
9

S
e
r
v
i
c
e

a
n
d

R
e
l
i
a
b
i
l
t
y

R
e
p
o
r
t

D
r
a
f
t

0
4
/
1
6
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2
0
0
9
38
St
a
f
C
P
R
_
0
7
9

A
t
t
c
h
m
e
n
t
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g
e

4
2

o
f

66
.
.
.
Su
s
t
a
i
n
e
d

I
n
t
e
r
r
u
p
t
i
o
n

C
a
u
s
e
s
Ta
b
l
e

4
.
1

-

%

S
A
I
F
I

p
e
r

C
a
u
s
e

b
y

O
f
f
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c
e
Th
e

f
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l
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w
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g

t
a
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l
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s
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s

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h
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p
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t
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e

S
A
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F
I

c
o
n
t
r
i
b
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t
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n

b
y

c
a
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s
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s

f
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o
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t
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g
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s

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x
c
l
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a
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t

d
a
y
s
.
Al
l
Re
a
s
o
n
CD
C
CO
C
DA
C
GR
C
KE
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LC
C
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C
PA
C
SA
C
SP
C
DP
C
Of
f
i
c
e
s
AN
I
M
A
L
13
.
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%
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2
%
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9
%
2.
5
%
3.
7
%
4.
6
%
2.
1
%
2.
1
%
3.
0
%
21
.
1
%
4.
3
%
9.
3
%
MI
S
C
E
L
L
A
N
E
O
U
S
0.
2
%
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3
%
0.
0
%
0.
0
%
0.
0
%
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0
%
0.
0
%
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%
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0
%
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0
%
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0
%
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1
%
PO
L
E

F
I
R
E
9.
8
%
5.
1
%
0.
6
%
7.
4
%
7.
1
%
4.
5
%
10
.
0
%
0.
0
%
0.
9
%
2.
9
%
0.
8
%
3.
8
%
WE
A
T
H
E
R
3.
4
%
20
.
9
%
80
.
6
%
29
.
3
%
26
.
6
%
14
.
5
%
31
.
4
%
28
.
6
%
22
.
2
%
21
.
5
%
22
.
0
%
25
.
4
%
UN
D
E
T
E
R
M
I
N
E
D
29
.
5
%
9.
5
%
2.
6
%
18
.
9
%
4.
0
%
25
.
2
%
5.
4
%
29
.
5
%
31
.
8
%
10
.
5
%
29
.
5
%
16
.
8
%
TR
E
E
5.
4
%
11
.
4
%
2.
3
%
7.
8
%
31
.
8
%
11
.
4
%
1.
0
%
12
.
4
%
16
.
7
%
7.
1
%
14
.
6
%
10
.
2
%
PU
B
L
I
C
17
.
9
%
1.
6
%
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4
%
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0
%
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2
%
1.
0
%
1.
7
%
5.
2
%
6.
2
%
10
.
5
%
14
.
1
%
6.
6
%
CO
M
P
A
N
Y
0.
0
%
6.
3
%
0.
0
%
0.
0
%
5.
2
%
13
.
5
%
0.
0
%
4.
8
%
7.
4
%
5.
4
%
0.
0
%
4.
5
%
EQ
U
I
P
M
E
N
T

O
H
18
.
7
%
5.
8
%
6.
0
%
4.
9
%
12
.
7
%
23
.
1
%
41
.
3
%
6.
6
%
7.
6
%
9.
3
%
8.
1
%
9.
7
%
EQ
U
I
P
M
E
N
T

U
G
0.
4
%
0.
8
%
0.
2
%
2.
5
%
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3
%
0.
6
%
0.
1
%
1.
1
%
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0
%
0.
9
%
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8
%
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9
%
EQ
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I
P
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T

S
U
B
0.
0
%
0.
0
%
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0
%
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8
%
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0
%
0.
0
%
0.
0
%
0.
0
%
0.
0
%
8.
8
%
0.
0
%
2.
9
%
PL
A
N
N
E
D
0.
9
%
36
.
0
%
5.
3
%
23
.
9
%
8.
4
%
1.
5
%
7.
0
%
9.
5
%
3.
0
%
2.
1
%
4.
8
%
9.
7
%
CD
C
CO
C
DA
C
DP
C
GR
C
KE
C
Co
e
u
r

d

A
l
e
n
e
Co
l
v
i
l
e
Da
v
e
n
p
o
r
t
De
e
r

Pa
r
k
Gr
a
n
g
e
v
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l
e
Ke
l
l
o
g
g
!

S
t
.

M
a
r
e
s
LC
C
OT
C
PA
C
SA
C
SP
C
Le
w
i
s
t
o
n
-
C
l
a
r
k
s
t
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n
Ot
h
e
l
l
o
Pa
l
o
u
s
e
Sa
n
d
p
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n
t
Sp
o
k
a
n
e
Av
i
s
t
a

U
t
i
l
t
i
e
s
20
0
9

S
e
r
v
i
c
e

a
n
d

R
e
l
i
a
b
i
l
t
y

R
e
p
o
r
t

D
r
a
f
t

0
4
/
1
6
/
2
0
0
9
39
St
a
f
C
P
R
_
0
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9

A
t
t
a
c
h
m
e
n
t
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g
e

4
3

o
f

66
.
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.
Ch
a
r
t

4
.
1

-

%

S
A
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F
I

p
e
r

C
a
u
s
e

b
y

O
f
f
i
c
e
Th
e

f
o
l
l
o
w
i
n
g

c
h
a
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t

s
h
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w
s

t
h
e

p
e
r
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t
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g
e

S
A
l
F
I

c
o
n
t
r
i
b
u
t
i
o
n

b
y

c
a
u
s
e
s

f
o
r

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t
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g
e
s

e
x
c
l
u
d
i
n
g

m
a
j
o
r

e
v
e
n
t

d
a
y
s
.
80
%
81
1
CO
C
DA
C
OR
C
KE
C
LC
C
OT
C
PA
C
SA
C
SP
C
DP
C
All

Of
f
c
e
s
AN
I
M
A
MI
S
C
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L
L
A
N
E
O
U
S
PO
L
E

FI
R
E
WE
A
T
H
E
R
UN
D
E
T
E
R
M
I
N
E
D
TR
E
E
PU
B
L
I
C
CO
M
P
A
N
Y
EQ
U
I
P
M
E
N
T

O
H
EQ
U
I
P
M
E
N
T

U
G
EQ
U
I
P
M
E
N
T

S
U
B
PL
A
N
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D
10
0
%
Of
S
A
I
F
I
Av
i
s
t
a

U
t
i
l
t
i
e
s
20
0
9

S
e
r
v
i
c
e

a
n
d

R
e
l
i
a
b
i
l
i
t
y

R
e
p
o
r
t

D
r
a
f
t

0
4
/
1
6
/
2
0
0
9
40
St
a
f
L
P
R
_
0
7
9

A
t
t
a
c
h
m
e
n
t
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g
e

44

of

66
.
.
.
Ta
b
l
e

4
.
2

-

%

S
A
l
O
l

p
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66
. Major Event Day Causes
Chart 6.1 - % SAIFI by Cause Code for the Major Event Days
The following char shows the percentage SAIFI contribution by causes for outages during major
event days
No Major events in 2009
.
.
Avista Utilities
2009 Service and Reliability Report Draft 04/16/2009
StafCPR_079 Attachment
53
Page 57 of 66
. Table 6.1 - % SAIFI by Sub Cause Code for the Major Event Days
The following table shows the SAIFI contribution and Customer hours by sub causes code for the
three main outage causes durng major event days.
Cause Code
POLE FIRE
Total
Sub reason
Pole Fire
SumofNi Sum of ri x Ni (hours)
No MED in 2009
TREE Tree Fell
Weather
Total
WEATHER Snow/Ice
Lightning
Wind
Total
.
.
Avista Utilities
2009 Service and Reliability Report Draft 04/16/2009
StafCPR_079 Attachment
54
Page 58 of 66
.Table 6.2 - Yearly Summary of the Major Event Days
Table 6.2 is provided as an initial review of Major Event Day information. The main premise of the
IEEE Major Event Day calculation is that using the 2.5bmethod should classify 2.3 days each year as
MED's.
The following table shows the previous major event days, the daily SAII value and the relationship
of the yearly T MED'
Year Date SAII TMED
2003 01-03-2003 5.38 4.96
05-24-2003 5.11
09-08-2003 5.47
10-16-2003 6.62
10-28-2003 9.25
11-19-2003 57.06
2004 05-21-2004 7.11 6.35
08-02-2004 7.36
12-08-2004 31.00
2005 06-21-2005 39.53 4.916
06-22-2005 9.03
08-12-2005 19.60.2006 01-11-2006 12.10 7.058
03-09-2006 8.58
11-13-2006 30.79
12-14-2006 29.26
12-15-2006 158.31
2007 01-06-2007 9.98 8.017
06-29-2007 32.64
07-13-2007 12.79
08-31-2007 21.30
2008 01-27-2008 17.57 9.224
07-10-2008 36.74
08-18-2008 9.49
2009 None 9.925
2010 11.110
.
Avista Utilties
2009 Service and Reliabilty Report Draft 04/16/2009
StafCPR_079 Attachment
55
Page 59 of 66
.
.
.
Interruption Cause Codes
MAIN SUBProposed Proposed
CATEGORY (Chanoes Only)CATEGORY (Changes Onlv)Definition
ANIMAL Bird Outages caused by animal contacts. Specific
animal called out in sub category.
Protected
Squirrel
Underground
Other
PUBLIC
Underground outage due to car, trck,
Car Hit Pad construction equipment etc. contact with pad
transformer, junction enclosure etc..
Overhead outage due to car, truck, construction
Car Hit Pole equipment etc. contact with pole, guy, neutral
etc.
Dig In Dig in by a customer, a customer's contractor, or
another utilty.
Fire Outages caused by or required for a
house/structure or fieldlforest fire.
Tree Homeowner, tree service, logger etc. fells a tree
into the line.
Other Other public caused outges
COMPANY Dig in Dig in by company or contract crew.
Other Other company caused outages
EQUIPMENT OH Arrestors Outages caused by equipment failure. Specific
equipment called out in sub category.
Capacitor
Conductor - Pri
Conductor - Sec
Connector - Pri
Connector - Sec
Crossarm- rotten
Cutout / Fuse
Insulator
Insulator Pin
Other
Pole - Rotten
Recloser
Regulator
Switch / Disconnect
Transformer - OH
Wildlife Guard Wildlife guard failed or caused an outage
EQUIPMENT UG URD Cable - Pri Outages caused by equipment failure. Specifc
equipment called out in sub category.
URD Cable- Sec
Connector - Sec
Elbow
Junctions
Primary Splice
Termination
Transformer. UG
Other
Avista Utilties
2009 Service and Reliability Report Draft 04/16/2009
StafCPR_079 Attachment
56
Page 60 of 66
.
.
.
MAIN Proposed SUB Proposed
CATEGORY (Changes Only)CATEGORY (Changes Only)Definition
EQUIPMENT SUB High side fuse
Bus Insulator
High side PCB
High side Swt / Disc
Low side
OCB/Recloser
Low side Swt / Disc
Relay Misoperation
Regulator
Transfonner
Other
MISCELLANEOUS SEE REMARKS For causes not specifically listed elsewhere
NOTOUR Customer equipment causing an outage to their
PROBLEM Customer service. If a customer causes an outage to
(Outages in this Equipment another customer this is covered under Public.
category are not
included in reported SEE REMARKS
statistics)
Other Utilty Outages when another utilly's facilties cause
an outaae on our svstem.
Used when water and contamination causes
insulator leakage current and fire. If insulator is
POLE FIRE leaking due to material failure list under
equipment failure. If cracked due to gunfire use
customer caused other.
PLANNED Maintenance /Outage, nonnally prearranged, needed for
Upgrade nonnal construction work
Forced Outage scheduled to repair outge damage
For outages when a tree falls into distribution
TREE Tree fell primary/secondary or transmission during
nonnal weather
Tree growth causes a tree to contact distribution
Tree growt primary/secondary or transmission during
nonnal weather.
Servce For outages when a tree falls or grows into a
service.
When snow and wind stonns causes a tree or
Weather branch to fall into, or contact the line. Includes
snow loadin!: and unloadino.
UNDETERMINED Use when the cause cannot be detennined
Outages caused by snow or ice loading or
WEATHER Snow/Ice unloading on a structure or conductor. Use
weather tree for snow and ice loading on a tree.
Lightning flashovers without equipment damage.
Lightning Equipment failures reported under the
equipment type.
Outages when wind causes conductors to blow
Wind into each other, another structure, building etc.
(WEA THERfREE\ used for tree contacts.
Avista Utilities
2009 Service and Reliability Report Draft 04/16/2009
StafLPR_079 Attchment
57
Page 61 of66
. Office Areas
.
.
Avista Utilties
2009 Service and Reliability Report Draft 04/16/2009
StafCPR_079 Attachment
58
Page 62 of 66
.
.
.
Indices Calculations
Sustained Interruption
. An interrption lasting longer than 5 minutes.
Momentary Interruption Event
. An interrption lasting 5 minutes or less. The event includes all momenta interrptions
occurng within 5 minutes of the first interrption. For example, when an inter:pting device
operates two, three, or four times and then holds, it is considered a single event.
SAIFI - System Average Interruption Frequency Index
. The average number of sustained interrptions per customer
. = The number of customers which had sustained interruptions
Total number of customers served
· = ¿N;
NT
MAIFIE - Momentary Average Interruption Event Frequency Index
. The average number of momentar interrption events per customer
. = The number of customers which had momentary interruption events
Total number of customers served
· = ¿IDEN;
NT
. MAIFI can be calculated by one of two methods. Using the number of momentar
interrptions or the number momenta events. This report calculates MAIFIE using
momentary events. The event includes all momentary interrptions occurrg within 5
minutes of the first interrption. For example, when an automatic interrpting device opens
and then recloses two, or three times before it remains closed, it is considered a single event.
SAIDI- System Average Interruption Duration Index
. Average sustained outage time per customer
. Outage duration multiplied by the customers effected for all sustained interruptions
Total number of customers served· ¿'iN;
NT
Avista Utilities
2009 Service and Reliabilty Report Draft 04/16/2009
StafCPR_079 Attachment
59
Page 63 of 66
~
. CAIDI- Customer Average Interruption Duration Index
. Average restoration time
. Outage duration multiplied by the customers effected for all sustained interruptions
The number of customers which had sustained interruptions
· = ¿r¡N¡
¿N¡
Quantities
i = An interruption event;
r¡ = Restoration time for each interrption event;
T= Total;
IDE = Number of interrupting device events;
N¡ = Number of interrpted customers for each interrption event during the reporting period;
NT = Total number of customers served for the area being indexed;
CEMln - Customers Experiencing Multiple Sustained Interruptions more than n.
. CEMIn
. = Tota Number of Customers that experience more than n sustained interruptions
Total Number of Customers Served
.. CNCJçn)
NT
CEMSMln - Customers experiencing multiple sustained interruption and momentary
interruption events.
. CEMSMIn
. Total Number of Customers experiencing more than n interruptions
Total Number of Customers Served
. CNTCk::n)
NT
.
Avista Utilities
2009 Service and Reliabilty Report Draft 04/16/2009
StafCPR_079 Attachment
60
Page 64 of 66
. MED - Major Event Day
A major event day is a day in which the daily system SAII exceeds a theshold value. Its purose is
to allow major events to be studied separately from daily operation, and in the process, to better
reveal trends in daily operation that would be hidden by the large statistical effect of major events.
T MED is calculated (taken from the IEEE 1366-2003 Standard)
The major event day identification threshold value, T MED, is calculated at the end of each reporting period
(typically one year) for use during the next reporting period as follows:a) Collect values of daily SAlOl for five sequential years ending on the last day of the last complete
reporting period. If fewer than five years of historical data are available, use all available historical data
unti five years of historical data are available.
b) Only those days that have a SAlOl/Day value wil be used to calculate the T MED (do not include days
that did not have any interruptions).
c) Take the natural logarithm (In) of each daily SAlOl value in the data set.
d) Find cx(Alpha), the average of the logarithms (also known as the log-average) of the data set.
e) Find ß(Beta), the standard deviation of the logarithms (also known as the log-standard deviation) of
the data set.
f) Compute the major event day threshold, TMED, using equation (25).
T - e(Ol+ 2.5 ß)MED-(25)
g) Any day with daily SAIDI greater than the theshold value TMED that occurs during the
subsequent reporting period is classified as a major event day. Activities that occur on days classified
as major event days should be separately analyzed and reported..
.
Avista Utilties
2009 Service and Reliability Report Draft 04/16/2009
SlafCPR_079 Attchment
61
Page 65 of 66
.
.
.
Numbers of Customers Served
The following numbers of customers were based on the customers served at the begining of the
year. These numbers were used to calculate indices for this report.
Office Customers 0/0 of Total
Coeur d'Alene 49531 13.8%
Colvile 17906 5.0%
Davenport 6852 1.9%
Deer Park 10419 2.9%
Grangevile 10119 2.8%
Kellogg/St. Maries 14178 4.0%
Lewis-Clark 29055 8.1%
Othello 6672 1.9%
Palouse 38208 10.6%
Sandpoint 14422 4.0%
Spokane 161401 45.0%
System Total 358763
Avista Utilties
2009 Service and Reliabilty Report Draft 04/16/2009
StafCPR_079 Attachment
62
Page 66 of 66
.
.
.
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-I0-0l / AVU-G-lO-Ol
IPUC
Production Request
Staff-089
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06110/2010
Patrck Ehrbar
Patrck Ehrbar
State & Federal Regulation
[phone]
REQUEST:
In the case of a customer receiving both electrc and gas servce, please provide a detailed
explanation summarzing all of the economic effciencies gained by providing electrc and natual
gas servce. In your response, please provide an executable electronic summar ilustrating each
class's anual percentage of Idaho dual servce customers over the last 10 years.
RESPONSE:
On page 16 in his testimony, Mr. Ehrbar noted that the only economic effciency for dual servce
customers is a reduction in biling expenditues. A recent estimate of the cost of biling (bil
preparation, paper supplies, postage, etc.) was 54.3 cents per bilL. Other potential savings for dual
service customers usually relate to servces and meter reading. As he discusses in his testimony,
there are no savings of dual serces as both require separate facilties to provide servce. Furer,
regarding meter reading, electrc and natual gas meter reading has been automated in our Idaho
facilties. The reduction in meter reaing expenses have already been included in the Company's
rates.
It is important to note that, even with the savings of 54.3 cents for dual servce customers, far more
fixed costs of providing serce to our customers (dual serce or not) are not being recovered in
the basic charge. The Company believes that it is appropriate to recover a more reasonable level
of these fixed customer costs though the basic charge.
StafCPR _ 089 Attachment A is an executable electronic sumar ilustrating each rate schedules
anual percentage ofIdaho dual servce customers from 2003 through 2009 (seven years). Data
for prior years was not readily accessible.
Schedule 1 2003 2004 2005 2006 2007 2008 2009.Dual Service Electric & Natural Gas 44,971 46,671 48,391 49,743 51,061 52,239 52,905
Single Service Electric 46,251 46,605 47,282 47,735 48,400 48,370 48,551
Total Schedule Customers 91,222 93,276 95,673 97,478 99,461 100,609 101,456
Percentage that are Dual Service Customers 49.3%50.0%50.6%51.0%51.3%51.9%52.1%
Schedule 11 & 12 2003 2004 2005 2006 2007 2008 2009
Dual Service Electric & Natural Gas 6,253 6,355 6,493 6,645 6,830 6,961 6,983
Single Service Electric 11,295 11,531 11,787 11,988 12,254 12,329 12,448
Total Schedule Customers 17,548 17,886 18,280 18,633 19,084 19,290 19,431
Percentage that are Dual Service Customers 35.6%35.5%35.5%35.7%35.8%36.1%35.9%
Schedule 21 & 22 2003 2004 2005 2006 2007 2008 2009
Dual Service Electric & Natural Gas 893 916 932 951 981 1,019 1,025
Single Service Electric 425 418 422 423 430 428 421
Total Schedule Customers 1,318 1,334 1,354 1,374 1,411 1,447 1,446
Percentage that are Dual Service Customers 67.8%68.7%68.8%69.2%69.5%70.4%70.9%
Schedule 31 & 32 2003 2004 2005 2006 2007 2008 2009
Dual Service Electric & Natural Gas 23 25 29 34 33 32 32
Single Service Electric 1,245 1,243 1,243 1,255 1,271 1,290 1,295
Total Schedule Customers 1,268 1,268 1,272 1,289 1,304 1,322 1,327
Percentage that are Dual Service Customers 1.8%2.0%2.3%2.6%2.5%2.4%2.4%
Schedule 101 2003 2004 2005 2006 2007.2008 2009.Dual Service Electric & Natural Gas 51,045 52,844 54,679 56,221 57,751 58,995 59,723
Single Service Natural Gas 10,723 11,593 12,522 13,151 13,634 13,915 14,056
Total Schedule Customers 61,768 64,437 67,201 69,372 71,385 72,910 73,779
Percentage that are Dual Service Customers 82.6%82.0%81.4%81.0%80.9%80.9%80.9%
Schedule 111 2003 2004 2005 2006 2007 2008 2009
Dual Service Electric & Natural Gas 774 793 798 819 842 869 871
Single Service Natural Gas 172 177 176 185 196 201 201
Total Schedule Customers 946 970 974 1,004 1,038 1,070 1,072
Percentage that are Dual Service Customers 81.8%81.8%81.9%81.6%81.1%81.2%81.3%
.
StafCPR_089 Attachment A.xlsx Page lof1
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-I0-0l / AVU-G-1O-01
IPUC
Production Request
Staff-092
DATE PREPARD:WISS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/09/2010
Bruce Folsom
KenBoni
Energy Solutions
[phone]
Please provide a comparative explanation and analysis ilustrating the Company's interpretation of
the similarties and differences between the serces Advantage IQ provides vs. Avista Utilties
DSM deparent. In your response, please explain how these similarties and differences might
evolve over time.
RESPONSE:
A vista Utilties specifically provides demand side management servces to customers residing in
its service tertory. A vista does not provide any servces that Advantage IQ offers to its national
client base. Avista Utilities does not provide any expense management services to any customers
in or out of Avista's service area.
Advantage IQ offers a comprehensive set of expense management servces needed to better
manage enterrise-wide utility, telecommuncations, waste and lease expenses associated with
business facilities typically involving national accounts with multiple sites and accounts.
Advantage IQ provides a centralized data base that helps customer better manage expenses,
identify areas for cost savings and improve effciencies for national accounts.
.
.
.
A VITA CORPRATION
RESPONSE TO REQUEST FOR INRMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-10-01/ AVU-G-I0-0l
IPUC
Production Request
Staff-97
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/11/2010
Elizabeth Andrews
Theresa Melvin
State & Federal Reg.
[phone]
REUEST: Please provide a list of all outside legal expenses incured by the Company durng
2009 and 2010 to date, with a brief description of the servces performed. If servces were
performed in support of a docketed state or federal court or regulatory action, please identify the
case name, case number and jursdiction.
RESPONSE:
Staff _PR _97 -Attachment A includes detail of all outside legal expenses incured by the Company
durng the test perod (twelve months ended December 31, 2009).
Staff_PR_97-Attachment B includes detail of all outside legal expenses incured by the Company
for the five months ended May 31,2010.
A general description ofthe majority of work performed for Avista in 2009 and 2010 follows:
Cascadia Law Group - Provides counsel on general water rights issues.
Davis Wright Tremaie LLP - Priar counsel to the Company with respect to
commercial transactions; also handles miscellaneous commercial litigation.
Provides counsel on hydro relicensing issues.
Dewey & LeBoeuf LLP - Provides counsel on a varety of corporate issues, including
proxy statement standards and exchange act compliance. Reviews and assists in the
preparation of Avista's filings with the Securties and Exchange Commission (10-K, 10-Q,
8-K, S-3, etc.) to ensure compliance with laws and regulations.
Ehlke Law Offices - Provides counsel on Labor and Industres' issues.
Garlington Lohn & Robinson - Provides counel on Montana streambed issues.
Paine Hamblin Coffin Brooke & Miler - Local counsel providing general litigation
support on a varety of corporate matters.
Pilsbur Winthrop Shaw Pittan - Provides counsel on Harbor Oil Superfud site issues.
Stoel Rives - Counsel to the Company on general corporate issues.
Van Ness Feldman - FERC counsel providing representation on a varety of matters,
including western power market issues, rulemakngs, etc.
West Payment Center - Payment center for Westlaw legal research.
Randall Danskin Attorneys - Provides counsel on a varety of HR and compensation
issues.
.
.
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AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-I0-01 / AVU-G-I0-0l
IPUC
Production Request
Staff-l 02
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/14/2010
Elizabeth Andrews
Jeane Pluth
State & Federal Reg.
[phone]
REQUEST:
Please provide a detailed description of the Clark Fork PM&E measures and projects for 2009 and
those planed and/or implemented for 2010. Please provide a list, in Excel format, of all charges,
by FERC account, for the 2009 PM&E measures and projects. The list should include the date,
vendor, amount, a brief description, and some method of tracking, i.e. voucher number or invoice
number.
RESPONSE:
The data requested was provided to Staff durng their on-site visit durng the week of June 14,
2010.
The data provided included the following; which are attached to ths response.
Staff_PR_I02-Attachment A - 2009 O&M Expenses for Clark Fork PM&E
StafCPR_102-Attachment B - 2009 Capital Spend for Clark Fork PM&E
Staff YR_l 02-Attachment C - 2010 O&MlCapital Budget Report for Clark Fork PM&E
Also, Staffwas provided actual transfers to plant for 2009 and for the 4 months ended April
30,
2010 in response to Staff Production Requests Nos. 028 and 029.
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JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-lO-Ol / AVU-G-I0-0l
IPUC
Production Request
Staff-l 03
DATE PREPARD:WISS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
06/14/2010
Elizabeth Andrews
Jeane Pluth
State & Federal Reg.
[phone]
For the Clark Fork Project, please provide a schedule showing the varous PM&E measures and
projects, by calendar year, for the PM&E's, including the cost for each project for the years 2002
though 2008.
RESPONSE:
Attached to this response the Company has provided (electronically only, due to the size of the
documents) the Anual Reports and the Anual Implementation Plans (Al) for 2002 through
2009, which includes the PM&E measures and projects, including the cost of each project. See the
folder called "Staff PR 103".
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYPE:
REQUEST NO.:
REQUEST:
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-1O-01 / AVU-G-I0-01
IPUC
Production Request
Staff-1 04
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/14/2010
Elizabeth Andrews
Jeane Pluth
State & Federal Reg.
[phone]
Please describe how actual Clark Fork Project PME expenditures from 2002 though 2009
compare to the expenditues origially specified for the period under the curent project license.
RESPONSE:
The Company provided (electronically only, due to the size of the documents) the Anual Reports
and the Anual Implementation Plans (Al) for 2002 though 2009 in response to StafCPR_I03.
The information requested is included in these documents. See the folder called "StaffYR_I03".
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION.JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
IDAHO
AVU-E-I0-0l / AVU-G-I0-01
IPUC
Production Request
Staff-105
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/14/2010
Elizabeth Andrews
Jeane Pluth
State & Federal Reg.
[phone]
REQUEST:
Please provide a narative description of how the collaborative group decides which projects to
approve, and how much to expend per project.
RESPONSE:
Avista owns and operates the Noxon Rapids and Cabinet Gorge hydroelectrc developments
(Clark Fork Project No. 2058). The operation of the Clark Fork Project is conditioned by the Clark
Fork Settlement Agreement (CFSA), signed in 1999, and Federal Energy Regulatory Commission
(FERC) License No. 2058, effective date of March 1,2001. The CFSA and FERC license
established Protection, Mitigation and Enhancement measures (PM&Es). The CFSA and FERC
license also established a number of committees and a process for the review and approval of the
implementation of all the PM&Es (see attached organizational char).
. The ultimate decision makng body is FERC, however, prior to A vista requesting FERC approval,
all proposed PM&E activities are approved by the Clark Fork Management Committee (MC). The
MC is comprised ofthe 28 signatories to the CFSA. The MC includes representatives from federal,
state, and local governent, five Native American trbes, non-governental organizations and
A vista. The MC strves to make all decisions, including approval of planed activities and
expenditues, by consensus.
The anual approval process begis on December 1 st of each year, when the first drafts of Anual
Implementation Plans (Als) are due to Avista. These draft Als are prepared by stakeholders
and/or Avista. During this month all aquatic Protection, Mitigation and Enhancement (PM&E)
Als (CFSA Appendix A, B, C, D, E, Fl, F2, F3, F4, F5 and T) are reviewed by the Aquatic
Implementation Team (Avista, IDFG, MFWP and USFWS fishery biologists). The first drafts for
the terrestral PM&Es are also due December 1 st of each year, and are developed by Avista with
input of our stakeholders. Depending upon the resource being addressed, these draft Terrestral
Als are reviewed and refined by subcommittees of the Terestral Resource Techncal Advisory
Committee (TRTAC established in the CFSA), such as the Riparan Implementation Team, Land
Use Subgroup, or Recreation Resources Subgroup.
.
Following this initial review process, all proposed individual projects that deal with stream habitat
restoration, habitat acquisitions/easements and total dissolved gas mitigation efforts are raned
and prioritized following established Management Committee (MC) approved raning criteria.
Usually, these types of proposed projects are found within Appendix A, B, Fl, H, and K. The
process is undertaken by interested participants from the Water Resources Techncal Advisory
Committee (WRTAC) and TRTAC composed of representatives from the CFSA signatories.
.
.
.
Page 2
After this ranng process, all of the draft Als, including the top raned stream habitat restoration,
habitat acquisitions/easements and total dissolved gas mitigation projects, are collated and mailed,
depending on subject category, to either the WRTAC or TRTAC for their review and
consideration. The Cultual Resources Techncal Advisory Committee also receives all of the
Als for their review and consideration. Formal meetings of these Technical Committees are held
toward the end of Januar where all Als are reviewed, modified and/or approved to be forwarded
onto the Management Committee.
After a short internal editing period, all of the draft Als are collated and mailed to the MC for
their review and consideration in the middle of Februar. During their March meeting, usually
held in the middle of the month, the MC reviews, modifies and approves the Als for the year. All
Als are then submitted for FERC approval by April 15th. Meeting notes from the Management
Committee and all subcommittees are available upon request.
.
.
.
JUSDICTION:
CASE NO:
REQUESTER:
TYE:
REQUEST NO.:
REQUEST:
A VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMTION
IDAHO
AVU-E-10-01 / AVU-G-I0-0l
IPUC
Production Request
Staff-106
DATE PREPARD:
WITSS:
RESPONDER:
DEPARTMNT:
TELEPHONE:
06/14/2010
Elizabeth Andrews
Jeane Pluth
State & Federal Reg.
[phone]
Please provide Staff access to any and all reports describing the Clark Fork PM&E projects that
have been planed or implemented.
RESPONSE:
The Anual Reports and the Anual Implementation Plans (Al) for 2002 through 2009 we
provided in response it Staff Production Request No. 103. Any additional reports wil be made
available to Staff upon request.