5/2/2024
1 RiversideCA.gov
1 RiversideCA.gov
UPDATE OF RIVERSIDE TRANSMISSION
AND RELIABILITY PROJECT
City Council
May 14, 2024
Public Utilities Department
RiversideCA.gov
2 The City Council has
engaged in a robust
discussion of the RTRP
over the last 14-months.
The time spent was
instructive and all options
to change the project
were exhausted.
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2 RiversideCA.gov
3 SCE’S PORTION OF RTRP
Approximately
5.9 miles of new
overhead 230-kV
transmission line
Approximately 4.1
miles of new
underground
230-kV
transmission line
New 230-kV
Wildlife
Switchyard
Modifications of
existing overhead
distribution lines
Modifications
at existing
substations
Telecommunication
facilities between the
existing Mira Loma
and Vista Substations,
and the proposed
Wildlife Switchyard
RiversideCA.gov
4 1. The RTRP Project Design has been underway for over 20 years
2. California Independent System Operator (CAISO)
ordered RTRP be built in 2009 for the benefit of Riverside and the City approved the project in 2013
3. CPUC granted CPCN Marc h 20, 2020 and on March 12,
2024 denied the City of Norco’s PFM
4. RTRP is an approved project to support capacity and
reliability of the electric system in the City
DECISION POINT
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3 RiversideCA.gov
5 Increase electricity capacity and improve electricity reliability in the City of Riverside
1. RPU is the only utility of our size with one point of interconnection to the regional grid
a. RTRP provides a second connection to the State’s grid
2. City experienced complete blackout in 2007
3. California Independent System Operator (CAISO)
ordered RTRP be built in 2009 for the benefit of Riverside
WHY WAS RTRP PLANNED
RiversideCA.gov
6 1. The Riverside Transmission and Reliability Project (RTRP) was designed and proposed to support a safe and reliable
electric distribution system that will serve the City’s existing customers as well as to support additional growth within the City’s limits.
2. Riverside’s current distribution system capacity is supporting electricity demand that exceeds the prudent operating
standards and practices of the electric utility industry to maintain a safe and reliable electric system.
3. The City’s electric loads will exceed the safe operating capacity under expected conditions by 2029 and potentially earlier if development projects continue to be approved.
NEED FOR THE RTRP HAS NOT CHANGED
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4 RiversideCA.gov
7 Total Remaining CapacityN-1 Condition
Loss of Transmission (already surpassed)
754 MW – 280 MW = 474 MW
RPU Summer Peak exceeds this capacity
Loss of one of two transformers at Vista
(loss of 280 MW capacity)
Loss of a Generation Asset
754 MW – 48.5 MW = 705.5 MWLoss of 1 RERC unit (loss of 48.5 MW capacity)
Loss of a Critical Infrastructure Transformer
754 MW – 97 MW = 657 MW
RPU Summer Peak almost exceeded this
capacity
Transformer loss in equipment connecting
RERC units to the distribution system
would result in the loss of generation from
two RERC units (loss of 97 MW capacity)
Note: The loss of both transformers at the Vista substation (loss of 560 MW capacity) would be what is considered an N-2 condition. RPU would only be able to serve 194 MW of load.
PRUDENT SYSTEM PLANNING
Operating
Standards
Plan for
Systems to
Support an
expected
weather event
with loss of one
critical piece of
infrastructure
RiversideCA.gov
8 1. Summer loads are expected
to exceed more than one
safe operating capacity
standard between 2024 and
2029
2. When capacity is exceeded
there will be rolling blackouts
3. It is not prudent to continue
to approve growth in loads
until a capacity solution is in
place
CONTINUING WITHOUT RTRP IS A RISK
Temperature Scenarios
1-in-201-in-101-in-51-in-2ActualYear
560.02021
648.02022
589.82023
660.4647.4631.4601.42024
670.3657.3641.3611.32025
682.1669.1653.1623.12026
693.4680.4664.4634.42027
704.8691.8675.8645.82028
720.1707.1691.1661.12029
726.6713.6697.6667.62030
RPU Actual and Forecast Peak Loads
(2021 through 2030)
Red indicates conditions that have the potential to exceed RPU’s total safe operating capacity for an Expected N-1 condition (657 MW for loss of transformer at RERC).
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9 System Capacity Compared to Forecast Peak Load
400.0
450.0
500.0
550.0
600.0
650.0
700.0
750.0
800.0
2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 Peak Demand (Load) and System
Capacity (MW)
Load for 1-in-2 Temperatures Load for 1-in-5 Temperatures Load for 1-in-10 Temperatures Load for 1-in-20 Temperatures Capacity at Vista Substation RERC Unit 1 Generation Capacity RERC Unit 2 Generation Capacity RERC Unit 3 Generation Capacity RERC Unit 4 Generation Capacity
Operating
Standards N-1
Capacity is 657
MW (loss of 1
bank of units at
Maximum Import
Capacity through
the Vista
Substation (560
MW)
RPU Maximum
System Capacity
RiversideCA.gov
10 1. The City and SCE entered an Interconnection Facilities Agreement (IFA)
a. Original agreement dated March 9, 2009 was amended on August 10, 2010 and March 23, 2018. The current agreement is dated January 15, 2019. b. Sets forth various rights and obligations of SCE and Riverside in connection with the development, ownership, and operation of the RTRP
2. IFA contains the RTRP development Obligations and Terms a. Facilities and cost allocation
b. Development responsibilities
c. Payment structure
3. FERC granted SCE an incentive ratemaking in the event the RTRP was abandoned
4. FERC would determine the allocation of costs for the RTRP in the event the IFA is terminated; SCE also has an avenue to recover costs through the IFA
AGREEMENTS BETWEEN THE CITY AND SCE
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11 1. Electric Utilities have an obligation to serve the community
2. If any options other than the immediate support to move the RTRP forward are to be further considered, RPU must act urgently to take steps to reduce and manage peak loads
3. Need to ensure safe operating standards are met to provide for safe and reliable electricity for RPU’s existing customers and to support future growth
4. Delays in taking action will increase the risk faced by the City of Riverside for future power outages and rolling outages during summer heat waves as well as financial risk to the City and customers
DISCUSSION
RiversideCA.gov
12 1. California Public Advocates Office study
showed that transmission projects in
California take an average 11.5 years
2. Majority of the time is planning, design,
permitting and intergovernmental agency
reviews
3. Construction takes a few years
a. A new transmission project will require years of
negotiation, design, environmental review and
approvals before it can begin construction
LARGE INFRASTRUCTURE PROJECTS TAKE TIME
Majority of time to
complete
transmission and
generation
projects is
planning, design,
environmental
review and
approval with
multiple
stakeholders and
agencies
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7 RiversideCA.gov
13 Riverside is growing and its electric demands are increasing
1. Projects already approved and thos e in review could add as much as 78 MW to RPU’s peak by 2030
a. Affordable and market rate housing for residents
b. Industrial, commercial and office spaces providing new jobs c. Expansions at universities and local schools are expanding opportunities for our community
d. Hospitals and medical centers are expanding to provide world class medical support for the entire region
2. Future growth and development will be planned over the next several years in the 2050 General Plan
3. 2023 legislation will not provide shor ter timelines for project design, approval, and development
TIME IS OF THE ESSENCE
RiversideCA.gov
14 1. RPU’s generation in the City of Riverside is aging a. Springs end-of-life expected 2028
b. RERC end-of-life expected 2039
2. Will need to be replaced by renewable and zero-emissions generation
3. Utility scale renewable generation is either not possible in Riverside (geothermal) or will take large land areas
1. Utility solar takes 5-10 acres of land to produce 1 MW of power when the sun is shining
2. To replace RERC’s 194 MW of power generation during the day would take between 1.5 and 3 square miles of land area
3. Large scale solar takes 4-5 years to design, permit and build
4. Riverside customers will solely bear the cost of building infrastructure within the City – electricity rates will increase
RIVERSIDE INTERNAL GENERATION
Existing power
plants will not
be able to be
replaced with
similar
technologies,
will take more
land and be
costly to
location in
Riverside
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15 1. Letter from SCE Chief Executive Officer, Steven Powell SCE has requested that the City take action to “firm[ly] and unconditional[ly] support the [RTRP]” including written confirmation that:
1. Riverside does not intend to challenge the CPUC’s denial of the Norco PFM or file a separate PFM or any other legal or regulatory challenge that would call for further reevaluation of the Project or D.20-03-001;
2. the “Working Group” Riverside previously convened to explore funding opportunities to support additional undergrounding of the Project will be disbanded and its actions terminated;
3. Riverside supports construction of Alternative 1 of RTRP as approved by the CPUC; and
4. Riverside will direct its staff, including Riverside Public Utilities, to resume activities in support of development of Alternative 1 (including coordination with SCE) without further delay.
2. Assembly Bill 3076 (Essayli)
OTHER CONSIDERATIONS
RiversideCA.gov
16 3. Wildfire Hazard and Risk
a. CPUC noted in its denial of the Norco PFM that fire hazard and risk were evaluated during its and the City’s evaluations and approvals of the RTRP
• CPUC noted that Norco had not provided new information that would justify a PFM
b. Fire hazard and risk maps have been updated but the hazard and r i s kd e s i g n a t i o ni nt h ep a t ho ft h eR T R Ph a v en o tc h a n g e do v e rt h e years
c. Transmission lines like RTRP present a lower fire risk than distribution lines
OTHER CONSIDERATIONS
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17 STRATEGIC PLAN ALIGNMENT
Priority 6 – Infrastructure, Mobility, & Connectivity
Goal 6.2: Maintain, protect and improve assets and infrastructure withing the City’s built environment to ensure and enhance reliability, resiliency, sustainability and facilitate connectivity.
Cross-Cutting Threads
Community Trust
Equity
Fiscal Responsibility
Innovation
Sustainability & Resiliency
RiversideCA.gov
18 That the City Council:
1. Receive an update regarding RTRP.
2. Direct staff to continue implementation of the City portion of the Riverside Transmission Reliability Project;
3. Direct Public Utilities Department staff to initiate a system capacity analysis and present findings and recommendations to the Board of Public Utilities to address short-term system capacity limitations in order to maintain safe, reliable and prudent operating standards; and
4. Direct the City Manager and City Attorney to request that Southern California Edison reinitiate, without d e l a y ,t h ec o m p l e t ec o n s t r u c t i o na n d operation of their portion of the Riverside Transmission Reliability Project.
RECOMMENDATIONS
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