20150717PAC to Staff 1-7.pdf

ROCKY MOUNTAIN
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Jean Jewell
Idaho Public Utilities Commission
472W. 'Washington
Boise, ID 83702-5918
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RE: ID PAC-E-I5-04
IPUC I't Set Data Request (1-7)
Please find enclosed Rocky Mountain Power's Responses to IPUC Data Requests 1-7.
If you have any questions, please feel free to call me at [phone].
Sincerely,
201 South Maln, Suite 2300
Salt Lake Citf Utah 84ll I
J. T.Z /u,/b1 /t-^
J. Ted Weston
Manager, Regulation
PAC-E-I5-04 / Rocky Mountain Power
luly 17,2015
IPIIC Data Request I
IPUC Data Request I
The Company mentions in Volume 1, Chapter 4 at the bottom of page 54 that it is
a member of the Northern Tier Transmission Group (I{TTG) and the Westem
Electricity Coordinating Council's (WECC's) Transmission Expansion Planning
Policy Committee (TEPPC). In relation to PacifiCorp's participation in these tu,o
or ganizations, p I ease :. explain whether the resulting regional and inteffegional plans result in a cost-
allocation framework that is suitable for PacifiCorp's investment and
ownership rights;o describe how PacifiCorp implements Powerflow or Production Cost Model
data improvements to TEPPC's Common Base Case and to NTTG's regional
analyses;. explain whether the Company's improvements to the transmission data are
provided to TEPPC or NTTG for future Common Base Case model
improvements; andr explain how the TEPPC and"/or NTTG analyses contribute to the Company's
transmission planning and benefit evaluation efforts.
Response to Data Request I
NTTG has established regional and interregional transmission planning and
cost allocation processes as approved by the Federal Energy Regulatory
Commission. Pacif,rCorp participates in those processes consistent with
requirements outlined in Attachment K of its Open Access Transmission
Tariff ("OATT"). PacifiCorp continues to plan for its local transmission
system consistent with OATT requirements.
PacifiCorp has member representation on the WECC reliability planning
committees and the NTTG planning committee that develop both power flow
and production cost modeling databases. In addition to submitting data
updates, committee members continue to work on developing assumptions
and modeling algorithms that improve modeling tools and more accurate
system dispatch results.
PacifiCorp submits data to both the TEPPC and NTTG forums, consistent
with commiuee specified guidelines and schedules. NTTG starts with the
TEPPC database and adds more definition that focuses on regional planning.
As one example of how PacifiCorp is contributing toward future common
base case model improvements, the company's representative on the NTTG
technical committee has been working with a counterpafi from Idaho Power to
improve and automate the "round trip" in GridView. The GridView system is
a production cost modeling tool that is used by boih TEPPC and NTTG.
NTTG uses the "round-trip" capability for exporting hours' of interest "raw
PAC-E-15-04 / Rocky Mountain Power
July 17,2015
IPUC Data Request t
data" from the production cost database to build upon for the power flow core
cases that allow for analyzing system reliability under different conditions of
stress.
As noted above, PacifiCorp continues to plan for its local transmission system
consistent with requirements outlined in its OATT. PacifiCorp participates in
the transmission planning efforts at both WECC and NTTG.
o Please refer to the responses above.
Recordholders: Shayleah LaBray (l&4) / Jamie Austin (2&3)
Sponsor: To Be Determined
PAC-E-15-04 / Rocky Mountain Power
hily 17,2015
IPUC Data Request 2
IPUC Data Request 2
The Company mentions in Volume 1, Chapter 4, near the bottom of page 48 that
the Company is "required to meet mandatory...reliability standards and planning
requirements." With respect to the Company's compliance with these regulations,
please:
describe how the Company's transmission planning and benefit evaluation efforts
address reliability challenges;
explain whether PacifiCorp performs a'round trip' analysis to estimate
transmission benefits (i.e., PCM - Power Flow - PCM); and
describe how PacifiCorp conducts dynamic stability analyses for future
transmission system improvements or mitigations.
Response to Data Request 2
T'he majority of transmission planning required is due to continuing growth of
electric demand on PacifiCorp's transmission system. Increasing demand
requires more transmission system capability, even if more transmission lines
and substations are not built. A large part of transmission planning in many
cases involves detemining how to increase the capacity of existing systems
without adding new lines and rights-of'-way. This is accomplished by
upgrading transmission lines and transmission systems throughout
PacifiCorp's balancing authority areas. Other reasons that transmission
planning is required include replacement of aging electric power
infrastructures, planning for relocation of transmission lines that must be
removed due to societal demands or changes in makeup of metropolitan areas,
or to lower the cost of power by reducing transmission congestion in the
Western Intcrconnection. ln meeting the challenges of an ever changing
transmission system, PacifiCorp is required on an on-going basis to perform
transmission planning studies that demonstrate performance results that are
measured against the North American Reliability Corporation and Western
Electricity Coordinating Council system performance criteria. System
performance issues that are identified as part of this process are mitigated by
development of new or modified grid operation procedures or transmission
projects that will be added to the 1O-year capital transmission improvement
plan.
PacifiCorp does not use o'round trip" analysis to estimate transmission
benefits. However, the company is investigating ways to use the round trip
constructively.
As part of the transmission planning studies that are conducted by PacifiCorp,
dynamic stability analysis is performed for system conditions and
contingencies that have previously demonstrated a potential for transient
instability. Dynamic stability studies are perfbrmed for all transmission
PAC-E-15-04 / Rocky Mountain Power
July 17,2015
IPUC Data Request 2
improvements or mitigations that may impact internal transmission paths or
major WECC transmission paths
Recordholders: Craig Quist (1&3) / Jamie Austin (2)
Sponsor: To Be Determined
PAC-E-15-04 / Rocky Mountain Power
July 17,2015
IPUC Data Request 3
IPUC Data Request 3
NTTG is currently analyzing an'ounsponsored project" for mandatory regional
cost allocations for additional transmission capacity for the Aeolus - Anticline -
Populus 500 kV. According to NTTG this alternative was identified by the
Technical Workgroup to solve overload on the Dave Johnston to Larumie River
230 kV line. Please provide the following:o the specific location of this project, including any interconnection points to
Pacifi Corp' s transmission or distribution facilities ;o the planned additional capacity from the additional transmission;o whether Pacif,rCorp's analysis confirms that this project is necessary for
regional transmission reliability; and. an explanation as to why PacifiCorp is not sponsoring this project.
Response to Data Request 3
The unsponsored project (Populus to Anticline to Aeolus) identified as part of
the NTTG 2014-2015 regional planning cycle includes 500 kilovolt facilities
that were located between southeast Idaho (Downey, Idaho) and southeast
Wyoming (Carbon County). Interconnection points of this project to the
PacifiCorp transmission system include: Populus 345 kilovolt, Bridger 345
kilovolt and Freezeout to Shirley Basin 230 kilovolt lines.
The NTTG Planning Committee identified the need for the unsponsored
project as part of the transmission reliability analysis. While the revised
NTTG 2014-2015 Biennial Study Plan provided an opportunity for
transmission needs vs. available transmission capacity to be assessed for
specific transmission paths, the determination of transmission capacity
increase associated with specific facilities additions is beyond the NTTG
purvierv and would be addressed under the WECC planning coordination
committee path rating process should the unsponsored project become a
sponsored project.
PacifiCorp participates in NTTG's regional transmission planning and cost
allocation efforts. The alternative project is the result of NTTG's regional
transmission planning analysis pursuant to its requirements under Order 1000.
The alternative project was borne from NTTG's regional transmission plan.
At this time, PacifiCorp has made no determination whether it would request
to sponsor the project.
Recordholders: Craig Quist (1&2) / Shayleah LaBray (3&4)
Sponsor: To Be Determined
PAC-E-I5-04 / Rockv Mountain Power
luly 17,2015
IPUC Data Request 4
IPUC Data Request 4
a. 1) The Company mentions in Volume 1, Chapter 4, near the bottom of page
48 that the Company's transmission system operations also respond to
requests made by Peak Reliability as the NERC Reliability Coordinator.
Please describe the services PacifiCorp obtains as a member of Peak
Reliability including senices such as the Enhanced Curtailment Calculator,
the Advanced Applications, or the third party certification of the Company's
physical security inventory. 2) Does PacifiCorp anticipate expanding its use
of any Peak Reliability services in the future?
b. How does the Company's transmission system operation, in response to Peak
Reliabi I ity requests, affect Pacifi Corp transmission planning?
Rcsponse to Data Request 4
a. I The enhanced curtailment calculator is in the conceptual phases and
therefore not in-service. T'he service is not anticipated until sometime in
2016. PacifiCorp does not currently use peaks advanced applications or
third party certification process.
a.2 PacifiCorp does not anticipate expanding its use of the peak RC
tools. The company has its own advanced applications (i.e. real-time
contingency analysis and state estimator).
b. Transmission system operations interfaces with transmission planning on a
daily basis, providing a free flow of information between the two
organizations. [f interaction with peak reliability identifies potential
system concerns requiring long term transmission solutions, such feedback
if provided to transmission planning by grid operations for further
evaluation.
Recordholder: Brent Roholt
Sponsor: To Be Determined
PAC-E-I5-04 /Rocky Mountain Power
July 17,2015
IPUC Data Request 5
IPUC Data Request 5
Regarding the Company's "Wind Integration Study" update that seeks to account
for estimated benefits from the Company's participation in the EIM (See Volume
2, Section H), please provide information on the following:
o how the Company estimates transmission congestion and how this is factored
in to the cost-benefit analysis;
o whether the Company is utilizing, or plans to develop or utilize, a "resource
sufficiency tool" to demonstrate adequate reseryes and resotrces for reliability
requirements compliance ;
r whether the Cornpany has reduced its regulating reserve requirement as a
result of its allocation of diversity benefits (See Volume 2, Section H, pg. 127 ,
first paragraph);
o a description of the Company's "regional flow tbrecast tool" that identifies
locations of transmission constraints; and
. if the Company's participation in "regulation pooling" is expected to increase
or decrease as a result of EIM participation.
Response to Data Request 5
o Estimating transmission constraints is accomplished using the Company's
Planning and Risk (PaR) model. The PaR model is a constrained optimization
model that solves an objective cost function subject to constraints that model
transmission congestion. The inputs to the PaR model consist of load and
wind forecasts, electricity and gas price forecasts, transmission forecasts,
estimated Energy Imbalance Market (EIM) benefits and required reserve
demand levels. The output of the PaR model is an estimated price of providing
non-contingency reserves of megauatt-hour (MWh).
o Participation in the EIM requires a formal passing of a resource sufficiency
test every hour, knovtm as the Flexible Ramp Sufficiency Test. This test
establishes required reserve levels for each lS-minute interval of the
upcoming hour. The test is published at three intervals before the upcoming
hour: (1) at 75-minutes before the start of the hour, (2) at 55-minutes before
the start of the hour, and (3) at 40-minutes before the start of the hour. The test
is limited to load, variable energy resources (VER) and uncertainty factor
regulation. It includes targets for following and regulation reserves, but does
not test for contingency reserve obligations (CRO).
Additionally, the Company estimates resource sufficiency for both planning
PAC-E- I 5-04 I Rocky Mountain Power
Iuly 17,2015
IPUC Data Request 5
reserves and operating reserves as part of its Integrated Resource Plan (lRP)
process. These assessments are detailed in the Company's most recent IRP,
the 2015 IRP, specifically Volume II, Appendix F (Flexible Resource Needs
Assessment) and Appendix I (Planning Reserve Margin (PRM) Study).
A diversity benefit has been recognized but not explicitly quantified,
Additionally, it is not part of the Flexible Ramp Sufficiency Test regulation
requirement (following and regulation reserves). It is anticipated to contribute
to the regulation requirement but the increased need for regulation is expected
to outpace the contribution of the diversity benefit as a result of VER
penetration.
The Company assumes that the request is asking whether it incorporates
transmission consfiaints in its cost-benefit analysis. Based on this assumption,
the Company responds as follows:
The transmission constraints are reflected by one of the inputs modeled in the
Company's studies for the IRP and wind integration study (WIS) transmission
topology. The Company uses a transmission topology that captures major
load centers, generation resources, and market hubs interconnected via firm
transmission paths. Transfer capabilities across transmission paths are based
upon the firm transmission rights of PacifiCorp's merchant function, including
transmission rights from PacifiCorp's transmission function and other regional
transmission providers.
It is anticipated that EIM participation will increase regulation pooling. It is
also anticipated that with increased VER penetration, increases in regulation
requirements will outpace the benefits of regulation pooling.
Recordholder: Tom Burns / Chris Miner
Sponsor: To Be Determined
PAC-E-15-04 / Rocky Mountain Power
July 17,2015
IPUC Data Request 6
IPUC Data Request 6
The December22,2014 memorandum to PacifiCorp from the 2014 Wind
Integration Study Technical Review Committee recommended that "future work
should explore balancing area cooperation between" the eastern and western
Balancing Authority Areas of PacifiCorp "under the EIM framework" (See
Volume 2, Section H, page 134).
o Please explain the steps taken by the Company to address this
recommendation.
o Please also explain whether the recent exchange of transmission assets with
Idaho Power furthers this type of coordination.
Response to Data Request 6
o The Company anticipates updating its wind integration study for the20l7
Integrated Resource Plan (lRP), and will consider how to best address
recommendations from the Technical Review Committee (TRC) at that time.
As described in the Company's 2014 Wind Integration Study (2014 WIS), by
participating in the Energy Imbalance Market (EIM), portfolio diversification
of load and variable energy resources provides a diversity benefit that reduces
PacifiCorp's regulating reserve requirement. The estimated diversity benefit
was captured in PacifiCorp's 2014 WIS as described in Volume II, Appendix
H, page 127 and 128 of the 2015 IRP. The diversity benefit was applied in
PacifiCorp's west balancing authority area (BAA) where there is a
transmission connection between PacifiCorp and the California Independent
System Operator (CAISO). PacifiCorp system resources are then used to meet
reserve obligations, net of assumed diversity benefits associated with
participating in the EIM, accounting for existing system transmission limits,
including limits between the PacifiCorp East (PACE) BAA and the PacifiCorp
West (PACW) BAA.
o The transmission asset exchange will significantly strengthen the dynamic
dispatch capability between PACE BAA and PACW BAA. PacifiCorp will
evaluate operating from the EIM when developing its next wind integration
study for the 2017 IRP.
Recordholder: Tom Burns / Rick Link
Sponsor: To Be Determined
PAC-E-15-04 / Rocky Mountain Power
July 17,2015
IPUC Data Request 7
IPUC Data Request 7
The Energy Storage Smeening Study was commissioned by the Company to
define energy storage technologies' applications among other purposes (See
Volume 2, Section Q, page 531). Please explain whether the Company is
evaluating the use ofenergy storage to address any distribution system issues.
Response to Data Request 7
The Company has begun to consider the use of battery storage as a potential
altemative to making feeder and substation upgrades in select circumstances.
Ian Andrews
Sponsor: To Be Determined