Rocky Mountain Power Sub
Transmission
Five Year Study
Findings and Kick Off
Attachment K Meeting
September 10, 2015
Rocky Mountain Power Area Transmission Planning
Area Transmission
Planning Manager:
Mark Adams
Area Transmission Engineers:
•
•
•
•
Bhavana Katyal
Talmage Daley
Jeremy Viula
Nathan Wilson
Studies Engineers
• Scott Murdock
• Nicole DeGiulio
© 2000 PACIFICORP | PAGE 2
Planning Engineers
Why Prepare the Studies?
© 2000 PACIFICORP | PAGE 3
– FERC/WECC required
– Provides a good round map for future
– Provides justification for new system additions
Who is invited?
Any individual is welcome
City and Municipal officials
Generation producers
Large industrial users
Equipment producers
© 2000 PACIFICORP | PAGE 4
–
–
–
–
–
Third Party Contributions
– Load and Forecast Projects
– New Points of Delivery
– Anticipated Future System Upgrades

Including block load increases
© 2000 PACIFICORP | PAGE 5
– System Power Flow Model
Basic Understanding of the Study
– Field Study
Document equipment
 Verify system ratings and settings

– Identify System Problems & Future Recommendations
– Generate a Report
Brief Understanding of the Area
 List Equipment ratings
 Fault duties, operation schemes
 Lists system “Problems and Future Recommendations”
© 2000 PACIFICORP | PAGE 6

Study Restrictions
– CIPS

The reliability of the energy grid depends not only on
physical assets, but cyber assets. The North
American Electric Reliability Corporation (NERC)
realized that, along with protecting the physical
assets, Critical Cyber Assets also need to be
protected to keep the energy grid secure.
© 2000 PACIFICORP | PAGE 7
– Confidentiality
Study Areas for 2015
Findings Reports
© 2000 PACIFICORP | PAGE 8
Goshen – Scott Murdock
Bhavana Katyal / Scott Murdock/
GOSHEN AREA STUDY
© 2000 PACIFICORP | PAGE 9
Need to review the LOADS before Friday
Goshen STUDY
The RMP substations range in voltage from 345
kilovolts (kV) to 46 kV on the high-side. The lines
range
capacity service
from 1028
mega volt amperes
TheinGoshen
area
(MVA) at 345 kV down to 20 MVA for the 69 kV
encompasses
and
46 kV lines. Theapproximately
focus of this study is limited to
the
transmission
includes 230 kV to
5600
squaresystem
mileswhich
spanning
46 kV and the substations served by these lines. The
portions of nine counties in
distribution system, 25 kV and below, will be
East Idaho.
addressed
only The
when Rocky
it provides solutions to
mitigate
loading
or voltage
Mountain
Power
(RMP)problems on the
transmission system i.e. distribution transfers.
Goshen Study Area
Figure 1.1
© 2000 PACIFICORP | PAGE 10
portion of this area is serviced
Presently
substation is
a source to 90 percent
by 56 Goshen
transmission
and
of the area distribution load. Amps and Antelope
distribution
substations
servesubstations
the rest. Others utilities:
Bonneville Power Administration (BPA), Idaho
Power (IP), and UAMPS all serve load in the area
which include some municipalities and REAs (rural
electric associations).
© 2000 PACIFICORP | PAGE 11
Goshen Study Map
Goshen STUDY
Municipalities/REAs:
– Idaho Falls City
– Fall River, Lost River, Salmon
River and Lower Valley Energy
© 2000 PACIFICORP | PAGE 12
– Rocky Mountain Power (RMP)
– Bonneville Power Administration (BPA)
– PacifiCorp Energy Supply Management
(ESM)
– PacifiCorp Transmission (PT)
– Idaho Power Company (IPC)
– Utah Associated Municipal Systems
(UAMPS)
Goshen Study
– Transmission voltages
studied include 230, 161, 138, 69 and 46 kV.
– There are 11 transmission line that go in/out of the
area at voltage levels of 345, 230, 161 and 115 kV
© 2000 PACIFICORP | PAGE 13
– There are 10 transmission
subs: Amps, Antelope, Big
Grassy, Bonneville, Goshen,
Rigby, Jefferson, St. Anthony,
Scoville, and Sugarmill
Goshen STUDY
Area Generation*
The Goshen area has hydro, wind, biomass and natural gas generation.
Hydro generation in the Goshen area is as follows:




8.2 MW
Rigby
Ashton (46 kV)
St. Anthony (46 kV)
0.7 MW
Rigby
Marysville (46 kV)
10 MW
Rigby
6.6
MW
Rigby
Felt (25 kV)
Palisades (115 kV)
184 MW
BPA (Goshen)
Berenice Feeder (25 kV) Total: approximately
7.5MW
Scoville
o Dry Creek (6 MW); Pancheri (0.16MW); Bell Mtn. (.25 MW)
o Sunny bar (0.45 MW); Nicholson (0.45 MW)
8 MW
Goshen
City Power Plant
26 MW
Goshen
Gem State
11.8 MW
Goshen
Lower Power Plant
Upper Power Plant
8 MW
Goshen
Wind generation in the Goshen area is as follows:
 Wolverine Crk/Jolly Hills Energy
 Meadow Creak Energy Units
 Horse Butte Phase I
Biomass generation in the Goshen area is as follows:
 Cargill
Natural Gas generation in the Goshen area is as follows:
 BYU-Idaho
PacifiCorp
Fall River Elect
CDM Hydro
USBR
Various
Idaho Falls Power
Idaho Falls Power
Idaho Falls Power
Idaho Falls Power
180 MW
120 MW
Goshen
Goshen
Invenergy
Meadow Crk Co, LLC
58 MW
BPA (Goshen)
BPA
Bonneville
Cargill Environmental
Financial
Rigby
Church of Jesus Christ of
Latter Day Saints
1.85 MW
5.6 MW
* All generation is considered variable and is not counted on for area support; see section 5 for more details.
© 2000 PACIFICORP | PAGE 14






Goshen STUDY
Transmission Lines in/out of the Goshen Area
Goshen - Kinport
Goshen - Three Mile Knoll
345
Antelope - Anaconda (Mill Creek)
Antelope - Brady
Antelope - Lost River
Goshen - Blackfoot
Goshen - Drummond
Goshen - Fishcreek - Grace
Goshen - Jefferson - Big Grassy
Anaconda (Mill Creek)
Goshen - Swan Valley
Goshen - Palisades
230
Loop
Loop
Loop
Radial
161
115
Loop
Loop
Ownership
Line
Line
Conductor Length
Size
(Miles)
2-795 ACSR
RMP
2-1272 ACSR
IPC
RMP/NorthWestern
1-1272ACSR
Energy
1-1272ACSR
IPC
1-795 ACSR
RMP/BPA
1-397.5 ACSR
IPC
1-795 ACSR
BPA
1-250 HHCU
RMP
IPC/NorthWestern
1-250 HHCU
Energy
1-556.5 ACSR
BPA
1-556.5 ACSR
BPA
41
52.82
200
58
31.42
19
~60
57.22
217.76
47
51.71
© 2000 PACIFICORP | PAGE 15
Line Name
Line
Line
Voltage
Configuration
(kV)
Load Growth
– Base System Loads
 Summer
2014: 652 MW
 Winter 2014-2015: 383 MW
– Growth
1.6%
 Winter: 2.2%
– Projected System Loads
 Summer
2019: 716 MW
 Winter 2019-20: 443 MW
© 2000 PACIFICORP | PAGE 16
 Summer:
Goshen STUDY
– System Improvements
items to maintain company standards
6 items of a risk management nature
© 2000 PACIFICORP | PAGE 17
10
System Improvements
Increase Capacity
Remove regulators
and Replace with a
new 30 MVA 69-25
kV LTC transformer
© 2000 PACIFICORP | PAGE 18
2015
Sandune 69-24.9kV Substation
Increase Capacity from 22.4 to 30 MVA
System Improvements
– Improve Voltage Control at Arco
© 2000 PACIFICORP | PAGE 19
2015
System Improvements
2016
2017
© 2000 PACIFICORP | PAGE 20
– Correct Clearance
Issues (Jefferson to Big
Grassy)
– Increase Capacity
(Goshen to Jefferson)
System Improvements
2017
© 2000 PACIFICORP | PAGE 21
Upgrade Belson
regulators replace
416 kVA units with
509 kVA units
System Improvements
© 2000 PACIFICORP | PAGE 22
Increase capacity on Sand Creek Tap
2018
© 2000 PACIFICORP | PAGE 23
System Improvements
2018
System Improvements
© 2000 PACIFICORP | PAGE 24
Mud Lake 69-12.47kV Substation
Increase Regulator Capacity from 416 to 509 kVA
2019
System Improvements
Upgrade Rexburg #2 regulators to 509 kVA
Rexburg Substation ~ Increase Capacity
161 kV to Rigby Substation
69 kV to St.Anthony Substation
SMD 1A, 200E
SMD 1A, 175E
Bank 2
14 MVA
Bank 1
22.4 MVA
Distribution
Feeder
Distribution
Feeder
Distribution
Feeder
Distribution
Feeder
Distribution
Feeder
Distribution
Feeder
2019
© 2000 PACIFICORP | PAGE 25
Replace the existing 416 kVA
regulators with 509 kVA regulators
System Improvements
2019
© 2000 PACIFICORP | PAGE 26
– Upgrade Ammon
regulator to 509 kVA
– Upgrade fuses to 175E
Construction Schedule Summary
Construction Schedule ~ Projects Required to Maintain Company Standards
2015 Construction - In service by end of this year
7-1
Sandune
7-2
Arco
Change out transformer. The existing unit has heating issues.this will also
increase capacity
Remove damaged regulators: Install 3-167 kVA regulators
$1,432,000
$350,000
2016 Construction - In service before May 1 of this year
7-3
Jefferson-Big Grassy
161 kV line
Correct clearance issues
$918,000
2017 Construction - In service before May 1 of this year
7-4
7-5
Goshen-Jefferson 161
kV line
Belson
Rebuild 29.5 line miles with 795 ACSR conductor
$15,968,000
Replace overloaded regulators with 509 kVA units
$350,000
2018 Construction - In service before May 1 of this year
7-7
Sand Creek 69 kV line Increase capacity:Rebuild 3.2 miles with 795 ACSR
Sugar City
Voltage Improvement: Install 2 stage 24 Mvar capacitor
$3,680,000
$3,531,000
2019 Construction - In service before May 1 of this year
7-8
7-9
7-10
Mud Lake Sub
Rexburg Bank #2
Ammon
Replace overloaded regulators with 509 kVA units
Replace overloaded regulators with 509 kVA units
Replace overloaded regulators with 509 kVA units
Grand Total
$350,000
$350,000
$350,000
$27,279,000
© 2000 PACIFICORP | PAGE 27
7-6
© 2000 PACIFICORP | PAGE 28
Goshen STUDY