hydropower value study past, present, and future€¦ · ramping resources to avoid load shedding...
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Hydropower Value Study –
Past, Present, and Future
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ABHISHEK SOMANI Energy and Environment Directorate, Electricity Infrastructure
Northwest Hydroelectric Association – Annual Conference, 2019
Portland, OR
February 28, 2019 2
Presentation Outline
Changes in Value Drivers for Hydropower
Changes on the Horizon Policy
Technology
Regulatory
Impacts on Power Markets and System Operations
DOE’s Hydropower Research Vision
Key Results from Hydropower Value Study
Changes on the Horizon:
More & More Variable Energy
Hydropower generators, due to their fast response, can provide ramping resources to avoid load shedding and variable energy curtailment and may be called upon to correct imperfect net-load forecast errors during intra-day and real-time operations to counteract variability and uncertainty.
State Goal Year
HI 100% 2045
CA 100% 2045
VT 75% 2032
NY 50% 2030
ME 40% 2022
CO 30% 2020
CT 27% 2020
NV 25% 2025
IL 25% 2026
OH 25% 2024
DE 25% 2026
Source: CAISO 2013
Summary of renewable portfolio standards (RPS) goals for several high-target states
February 28, 2019 4
Changes on the Horizon:
CAISO Net Load and Renewables Supply
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Renewables Supply – October 2, 2018
Solar Wind Geothermal Biomass
Biogas Small hydro Batteries
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35000
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Load vs Net Load – October 2, 2018
Hour ahead forecast Demand (5 min. avg.) Net demand
Max Load served by Renewables
% o
f To
tal L
oad
CAISO estimates that by 2024 there will be
times during certain days when 100% energy
will come from variable energy resources
Systems will require increasing amounts of
operational flexibility
Systems with an excess of must-run
resources will experience negative pricing,
forced curtailment, or export.
Energy production shifting from conventional
resources to Variable Energy Resources
Source: CAISO
February 28, 2019 5
Flattening Supply and Low Prices dues to
Increasing Renewables – PJM Example
Load growth has stayed
relatively flat over the years
Supply curve has shifted
right causing decrease in
energy prices
Increasing renewable
penetration – mostly
wind
Source: PJM State of the Market Report
February 28, 2019 6
Changes on the Horizon:
Technology – Energy Storage
CAISO – predominantly
reliability oriented
requiring at least 4
hours of energy
capacity to fulfill CPUC
requirements
ERCOT and PJM
installations are geared
for frequency regulation
and hence, tend to be
power-oriented
Source: US EIA Form EIA-860M
Source: US EIA Form EIA-860
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Current Power Market Trends
Low energy prices, because of high penetration of zero-production
cost renewables, and low natural gas prices. There are low prices in
day-ahead and real-time markets, and hence, even with the inherent
volatility is causing some of that shift along with growing comfort of
participants to rely on markets to meet their needs.
Flat demand even in a growing economy. Electricity demand is flat.
Greater demand-side efficiency reduces overall loads but may make
them “peakier.” Investment strategies and planning paradigms need to
shift to ensure adequate levels of flexibility exist.
Decreasing ancillary services needs and prices. This is a trend seen
in all ISOs with the exception of CAISO, and is due to increased
sophistication in renewables forecasting methods and integration as well
as a growing comfort of system operators with given reserve margins.
February 28, 2019 8
Current Power Market Trends:
All-in Prices Across Markets
Prices have stayed the same over the years across markets
https://www.potomaceconomics.com/wp-content/uploads/2018/05/2017-State-of-the-Market-Report.pdf
February 28, 2019 9
Regulation Reserve Requirements –
ERCOT Example
Regulation Up
Regulation Down
Regulation
requirement in
ERCOT market has
decreased due to
improvements in
forecasting, and
other operating
procedures
Trends in other
markets are mixed:
CAISO increased
its requirement
from 400 to 800
MW in early 2016
Source: http://sites.utexas.edu/energyinstitute/files/2016/12/UTAustin_FCe_Ancillary-Services_2016.pdf
February 28, 2019 10
Reliability Impacts:
NERC CPS1 Score – ERCOT Example
Reliability, as measured by NERC CPS1 score has increased over time
Source: http://sites.utexas.edu/energyinstitute/files/2016/12/UTAustin_FCe_Ancillary-Services_2016.pdf
February 28, 2019 11
Changing Paradigm of Renewable
Operations and Contract Structures
Flexible operations of VERs being proposed
Hawaiian Electric Co. signed contracts for
dispatchable renewables
Question: What are the implications for
hydropower fleet and operations?
Plant nameplate capacity: 300 MW Power output curtailed during these operating hours to maintain headroom for inertia and primary frequency response
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Changes on the Horizon:
Power Market Changes
New market products to meet
increasing flexibility requirements:
Ramping/flexible capacity
Product expansion, increasingly
granular products
Intra-hour scheduling, dispatch, and
settlement
Western market convergence
CAISO administered Energy Imbalance
Market (EIM) footprint growing
More and more balancing authorities
participating in the EIM
Discussions ongoing regarding
consolidation of western BAs under a
single ISO/RTO
February 28, 2019 13
Greenhouse Gas Compliance in the
Energy Imbalance Market – 2017
Almost 65% of the compliance obligations were assigned to hydro
GHG emissions prices were less than CEC established compliance costs
for an efficient gas resource
February 28, 2019 14
Changes on the Horizon:
Market Design Changes in other parts
PJM considering a change to the existing price formation process by
allowing inflexible units to set market prices
Pros: Avoids out-of-market settlements;
Cons: Unintended consequences not well known, presently
ERCOT considered redefining ancillary services products but the
initiative failed after a lengthy stakeholder process
Some of the ideas are in the process of being implemented, such as fast
frequency response reserves
CAISO presently engaged in design and analysis of a day-ahead
ramping reserve product
CAISO has added a new category of requirements to the Resource
Adequacy (RA) program called Flexible Resource Adequacy
February 28, 2019 15
Changes on the Horizon:
Ramping Resource Adequacy in CAISO
Category 1 –
Base Ramping Category 2 –
Peak Ramping Category 3 –
SuperPeak Ramping
Economic Bid – Must offer Obligation
5:00AM – 10:00PM 5 hour block 5 hour block
12 PM to 5 PM for May – September 3 PM- 8 PM for January- April and October-December
Energy Requirement Minimum 6hrs at Effective
Flexible Capacity (EFC) Minimum 3hrs at Effective
Flexible Capacity (EFC) Minimum 3hrs at Effective
Flexible Capacity (EFC)
Daily Availability 7 days a week 7 days a week Non-Holiday Weekdays
Maximum quantity of capacity allowed
Set monthly based on largest secondary net load
ramp
Set based on the difference between 100% of the
requirement and category 1
Maximum of 5% per month of the total requirement per
month
Daily start-up capability
Minimum of 2 starts per day or the # of starts allowed by
operational limits as determined by min up and
down time
At least 1 start per day At least 1 start per day
Other limitations No limitations that translate
to less than the daily requirements
No limitations that translate to less than the daily
requirements
Must be capable of responding to at least 5 dispatches per month
Examples of types of resources
Conventional gas fired resources, wind, hydro,
storage with long discharge capabilities
Use-limited conventional gas fired generation, solar,
conventional gas fired peaking resources
Short discharge battery resource providing
regulation and demand response resources
DOE-WPTO Hydropower Value
Research
February 28, 2019 16
Hydropower Value Study
Study funded by Department of Energy’s (DOE’s)
Water Power Technologies Office (WPTO)
Project Team:
Argonne National Laboratory (Argonne)
Idaho National Laboratory (INL)
National Renewable Energy Laboratory (NREL)
Oak Ridge National Laboratory (ORNL)
Pacific Northwest National Laboratory (PNNL) – Project Lead
Timeline
Start date: March 2018
End date: March 2019
Project Overview
Motivating questions:
How is hydropower currently contributing to grid services?
What services/capabilities will be needed by the grid in the future?
Can hydropower provide the services based on technical capability and cost?
Project intent:
Foundational work to understand present hydropower operations trends, future expected changes, and hydropower capabilities analysis
Project design:
Will involve extensive data collection and analysis on market participation trends, operational practices, and technological capabilities
Will not involve design of new market rules, hydro operations models/tools
Expected outcomes:
Comprehensive understanding of hydropower’s evolving value proposition
Understanding of high-impact future research needs – research roadmap
Analysis of Hydropower
Operations in the US
February 28, 2019 19
TOM VESELKA – ARGONNE NATIONAL LABORATORY NATHALIE VOISIN – PACIFIC NORTHWEST NATIONAL LABORATORY RUI SHAN – OAK RIDGE NATIONAL LABORATORY
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WECC: Hydropower Production Is Dispatchable Following
Loads More Effectively than other Renewable Resources
Combined Loads & Generation for the CISO & BPAT BAs
Shifting operations from load following to maximizing value based on market prices would change hydropower economics
CAISO: Hourly averaged correlations
between solar and small hydro
By Power Output By Percent of Generating Mix
Small hydro’s increase in generation during both the morning and afternoon peak periods when solar PV increases, on a daily basis.
Small hydro’s proportional increase especially during the morning peak, but also across all the hours of the day when solar PV increases.
Analysis by: Rui Shan
February 28, 2019 22
ISO-NE: Ancillary Services Participation
Capacity payments represent majority of non-energy revenue
Spinning Reserve and Black Start provide more revenue than Regulation, Supplemental
Reserve and Voltage Support
0
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2008 2009 2010 2011 2012 2013 2014 2015 2016 2017
$/k
W
Energy Others
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Capacity Payment Blackstart Regulation Spinnning
Supplemental Voltage support Uplift
Generation: PSH plants generate most of the times during high price periods, as expected
MISO: Patterns of Pumped Storage Hydro
Generation and Pumping
Pumping: PSH plants operate in pumping most of the times during low price periods, as expected
February 28, 2019 24
Chelan PUD – Impact of Water Availability
on Hydropower Operations
Water availability, and resultant water management issues impact operations
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Significant hydropower services, which
may or may not be effectively monetized
Rotating mass / Inertia
This property has been historically abundant in the system
Inertia can be synthetically produced, but failure to have enough will cause
system frequency (60 hZ) to deviate
Primary Frequency Response. Hydropower is considered a fast and
accurate responding market participant. But the speed of signal matters:
California ISO notes that hydropower’s provision of primary frequency response (less
than a minute) is “predictable,” but its performance is relatively sluggish and inaccurate
due to older hydropower plants using mechanical controls as a proxy for power signals
Flexibility. Hydropower can contribute many services. Resources are
compensated on a competitive basis for each service that they provide,
but not for their ability to provide multiple services depending on the
need.
Inertial and Governor Response: Resource-level Responses
Hydro resources are typically programmed to provide governor response, along with the autonomous inertial response
Inertial and Governor Response: System Response
System recovers because of both inertial and governor response System blackout because
of lack of governor response
Basis for CAISO’s Transferred Frequency Response Obligation Construct
February 28, 2019 28
Changes on the Horizon:
Market-based Mitigation Measures
Planned mitigation measures are shown in blue, while already existing mitigation
measures are shown in black; Source: ERCOT
Future Grid States:
Implications to Hydropower
Operations and Value
MICHAEL INGRAM – NATIONAL RENEWABLE ENERGY LABORATORY
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Hydropower Value Drivers in Future Grid
Flexibility
• “Duck” Curve
Reliability
• Black Start
• Reactive Power Support
Ancillary Service
• Operating Reserves
Economics
• Operational Costs
• Value
Stability
• Frequency Response
• Transient Stability
Power Systems Metrics
Report the inferred value of hydropower based on the impacts and requirements identified in literature review and the NREL Interconnections Seam Study.
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Examples: Model vs. Actual
Glen Canyon Dam and Blue Mesa
Gaps and Challenges in Hydroelectric
Representation in Power System Models
Precipitation, Runoff, and Unregulated Flow Variability
Pool (Elevation) Variability
Temperature and Water Quality Variability
Individual Organism Response & Growth
Population Response & Growth
Community Response
Landscape & Riverscape Adj.
Turbine, Gate, and Flow Dynamics
Power System Dynamics
Water Demand & Competing Use Variability
Automated Controls
Real-Time Scheduling
Short-Term Planning
Long-Term Planning
Hydrologic Variability
Ecological Variability
Equipment & Use Variability
Decision-Making Processes
Comparison of Hydropower Operations Timescales and Power System Time Scales (courtesy of ORNL)
Hydropower in power system operations
Hydropower represented as a monthly potential at the balancing authority scale
• Spatial, temporal, unit and computational complexity creates seams issues between water management and grid models
• Hydropower representation presently does not depict the complexity, diversity, and changed operational paradigm of the fleet
February 28, 2019 33
Key Takeaways
Power grids and markets are evolving, and conventional value streams
may no longer be the most valuable
Some evidence of changes in operations – Helms (PG&E)
More system-wide work is needed to asses flexibility characteristics
Further economic analysis is needed to assess the cost vs. benefit of
operating resources more flexibly
System stability and reliability needs with increased renewables will
impact hydropower operations – more analysis needs to be performed
HVS Project Core Tasks
Landscape analysis
More granular exploration of how hydropower is used, and how it is valued
Contribution to reliability services presently not monetized:
Inertia and primary frequency response
Future value drivers
Possible evolution of the power system, and
Implications on demands that could be placed on hydropower resources
Capabilities and Constraints
Technical and water management drivers of flexibility
What does it cost to be flexible?
February 28, 2019 35
Key Takeaways
System Reliability: More than
100% increase in uplift service
by hydro in ISO-NE from 2015
to 2016; indicates fast-start
capability hydro units
0
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200
300
400
500
600
2008 2009 2010 2011 2012 2013 2014 2015 2016 2017
$/k
W
Energy Others
Hydropower in ISO-NE
Flexibility is resource specific, and depends on
water availability and environmental requirements
Power grids and markets are evolving, and conventional value streams may no longer be the most valuable
Flexible Operations:
Some evidence of changes in
dispatch of small hydro (CAISO)
due increasing PV penetration
Hydro resources presently provide
10% of CAISO-wide Flexible
Resources Adequacy requirement
36
Challenges Facing Hydropower Valuation
Valuation methodologies and mechanisms. As presently defined,
market products and services will not adequately justify investments in
capital intensive projects and technologies. Value drivers such as
resilience, reliability, and flexibility are not explicitly priced. For example,
with flexibility, a resource may be compensated for a specified service,
but not its ability to perform any one of several services at a given
moment.
Complex interface between markets and operational parameters,
including water constraints. System-driven optimization (like PJM) of
hydropower may not present the entire suite of value streams to the
resource.
37
Changes on the Horizon:
Regulatory Shift
FERC decisions adjusted market requirements to accommodate
energy storage.
Order 841 (February 2018), FERC issued Order No. 841 requiring system
operators to remove barriers to the participation of electric storage resources
in the capacity, energy, and ancillary services markets. Each ISO/RTO must
revise its tariff to include market rules that recognize the physical and
operational characteristics of electric storage resources.
Order 842 (February 2018),
February 28, 2019 38
Changes on the Horizon:
Technology – Electric Cars
Grid Impacts:
Significant increase in energy consumption
Change in load shapes, not presently known
Potential significant increase in instantaneous power requirement
39
Reservoir Water Storage Reduces Variability and
Significantly Adds to Hydropower’s Value
Generation (MWh)
Gen is highest during peak load month
Monthly inflow variability is much greater than outflow variability
The ability to reduce variability and shift water releases/generation to high value months is a function of storage capacity
February 28, 2019 40
Changes on the Horizon:
Technology – Energy Storage
State mandates:
California – 1325 MW (AB 2514, 2013) + 500 MW (AB 2868, 2017)
Massachusetts – 200 MWh by 2020
New York – 1.5 GW by 2025
State incentives:
Nevada – Allows energy storage systems to be included in RPS
Maryland – 30% ITC on residential and commercial systems
Some states require IOUs to include energy storage in IRPs
PG&E’s 500MW/2270 MWh storage procurement:
Three projects from third-party owners, totaling 385.5 MW, 1,540 MWh, and
One 182.5 MW, 730 MWh project the utility would own