20190208Major Event Report (3).pdf

Y ROCKY MOUNTAIN
FOWER
AIrVrSrOrOf aAdFr@RP
r":Ic IlvLij
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1407 West North Temple
Salt Lake City. Utah 84116
February 8,2019
VIA OVERNIGHT DELIVERY
Diane Hanian
Commission Secretary
Idaho Public Utilities Commission
472West Washington
Boise, Idaho 83720-5983
RE: Roclry Mountain Power Major Event Report
Dear: Ms. Hanian
Rocky Mountain Power is requesting designation of the December 30-31, 2018 outage and the
consequences thereof to be classified as a major event and excluded from its performance results
due to the day's performance, which exceeded the Company's major event threshold of 1,333,663
customer minutes lost in a 24-hour period.
Attached you will find details regarding the major event including restoration resornces, number
of customers offsupply, total customer minutes lost, as well as SAIDI, and SAIFI figures.
Rocky Mountain Power will exclude outage information for this event from its network
performance reporting and from customer guarantee failure payments.
If you require further information regarding this report please contact Heide Caswell, Network
Performance Director, at [phone].
Sincerely,
-lD*kdhtfoin'wa/tu
Douglas N. Bennion, P.E.
Vice President
Engineering Services & Capital Investnent
cc Bev Barker,IPUC
c'rnhlJ I\J I1
Report to the Idaho Public Utility Commission
Event Date:
Date Submitted:
Primary Affected Locations:
Primary Cause:
Exclude from Reporting Status
Report Prepared by:
Report Approved by:
December 30-31, 2018
February 8,2OL9
Rexburg/Shelley
Storm
Yes
April Brewer
Heide Caswell/Dan Bodily/Seth Riding
Event Description and Restoration Summary
On the morning of December 30, 2018, Rocky Mountain Power customers in Rexburg and Shelley, ldaho,
begin experiencing outages as a winter storm brought snow, ice, and high winds, damaging equipment
across the region. Strong wind gusts also caused several lines to make contact, creating electrical faults
which tripped circuit breakers at numerous substations.
During the two day event 630/o of all customer minutes lost and 73Yo of all customer outage events were
the result of loss of supply outages, as transmission lines experienced fault operations from the heavy
wind gusts. As a result, grid operations reconfigured transmission service to minimize fault operations
by switching lines in the path of the storm to those lines fed from areas which were not as heavily
impacted by the weather. ln addition to the loss of supply caused outages, wind related events
accounted for 33Yo of all customer minutes lost and 2lo/o of all customer outage events. ln total,
129 sustained outages caused L9,269 customer interruptions (some customers may have experienced
multiple events), with an average outage duration of 4 hours 35 minutes . At 6:27 am on December 31st
the total customers out peaked at L2,676.
Weather conditions complicated restoration activities, as high winds created a safety hazard for line
crews, delaying the repairs to some outages as crews were limited to restoration activities which did not
require the use of some equipment, such as bucket trucks. Crews from across the region were
dispatched to assist in restorations activities. There were two customer complaints made regarding the
major event.
# lnterruptions (sustained events)115
Total Customer lnterrupted (sustained events)19,269
Total Customer Minutes Lost 5,317,tto
State Event SAIDI lmpact 56.5 minutes
CAIDI 276
Maior Event Start L2/30/20t8 8:37 AM
Major Event End L213L12078 7:28 PM
Event Outage Summary
Lof 4
Electric Service Reliability - Major Event Report lD-18-3
The graphic below displays the extent and duration of the event in the heaviest hit region.
Restoration lntervals
F
Customer Outage
Duration (in hourcl
Ixrfib(rtirfl Unc
I BycrtuitColon
I CurtorncrOfigcs
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a 18 <. valu. < 24
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19,269 8,890 to,379 0
Total Customer Sustained
Outage Events < 3 Hrs.
(entire or event period)
3 - 24 Hrs. 24+ Hrs
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Restoration Resources 1
State Estimated Major Event Costs 1
Major Event Declaration
PacifiCorp designates these events and the consequences thereof a major event in accordance with
docket PAC-E-04-07, where the company and commission agreed that determination of major events
will be made by applying IEEE standard 1366-2003 methodology (commonly referred to as the 2.5 beta
method), wherein a statistical outlier of these extreme events is based on the state daily SAIDI
thresholds. The company's 2018 ldaho reliability reporting region threshold is 1,333,663 customer
minutes lost (15.67 SAIDI minutes) in a 24-hour period.
1 Data provided represents specific system records for personnel, resources, and costs; and is specific to the event, not inclusive of state
delineation. However additional resources whose participation did not get individually captured in transaction recording systems were
utilized during the event, thus the data presented here effectively understates the resources, including cost, involved in restoring the
system to normal.
line Crewman 25
Support Staff 1
Troubleman 4
Foreman 5
Administrative 1
Substation Crewmember 9
TOTAT 45
Personnel Resources
SO
So
s1,256
s2,093
Capital
Expense
$L9,757
S55,tts
S3,840
s264
S24,8s3
567,472
Total 584,872 $o s3,349 54,to4 $92,32s
Estimate S Labor Contracts Materials Overheads TOTAL
3 of 4
Event Details
CustomersOllt vs. Time ldaho Maior Event
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SAlDl, SAlFl, CAIDI by Rellability Reportint Region
Please see the attached system-generated reports.
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