assessing impacts in california’s self-generation incentive program (sgip) presentation to demand...
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![Page 1: Assessing Impacts in California’s Self-Generation Incentive Program (SGIP) Presentation to Demand Assessment Working Group George Simons, Director Itron](https://reader035.vdocuments.pub/reader035/viewer/2022062713/56649ceb5503460f949b70a7/html5/thumbnails/1.jpg)
Assessing Impacts in California’s Self-Generation Incentive Program (SGIP)
Presentation to Demand Assessment Working Group
George Simons, Director
Itron
August 16, 2013
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Itron, Inc. Overview
Leading technology provider to global utility industry
110 million communication modules
8,000+ customers in 130 countries 8,000 employees $2.4 billion (2011 USD)
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© 2009, Itron Inc. 3
Itron: Consulting and Analysis Group
Who we are: Part of Itron’s Professional Services Group Staff of ~80 C&A Professionals
Economists, Engineers, Statisticians, Load and Market Researchers Offices in Oakland, CA; San Diego, CA; Davis CA, Vancouver, WA; and Madison, WI
What we do: Energy Efficiency Demand Response Renewables and Distributed Generation Load Research Market Research Integration of Resources (IDSM and Smart Grid)
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Renewables and Distributed Generation Strongly focused on generation located on the distribution side of
the electricity system Includes solar (PV and thermal), wind, biomass and conventional and
renewable-fueled generation and combined heat and power (CHP) Services include:
Market assessments for DG/renewables/CHP Program and project performance evaluations Cost-effectiveness and economic analyses Advanced DG technology cost and performance assessments Sub-metering for evaluation and performance monitoring Assistance related to integrating DG technologies into the grid
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Itron’s Role in the SGIP Itron has been the SGIP prime evaluator since 2001 Services:
Impacts evaluation Process evaluation Performance metering Cost-effectiveness analysis Topical reports and products
Examples of products 11 annual impact evaluations 22 semi-annual renewable fuel reports DG cost-effectiveness framework (2005) SGIP cost-effectiveness evaluation (2007) DG Cost-effectiveness study and model (SGIPce) 2011 Optimizing Dispatch and Location of Distributed Generation (2010)
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SGIP Impacts Evaluations Evaluations cover:
Status of program Critical trends Energy impacts
Annual Coincident peak demand
Transmission and distribution impacts Compliance with efficiency requirements
Useful thermal (waste heat recovery) Overall system efficiency
Reliability and performance Greenhouse gas impacts Foreward look at SGIP
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Overall Approach on Assessing Impacts SGIP population of technologies is varied
Legacy systems (IC engines, microturbines, gas turbines, fuel cells, wind) New systems (fuel cells, wind, storage)
Based on statistical sampling Targeting 90% confidence with 10% precision
Some legacy systems we can only achieve 70/30 Determine sample based on strata
Metered data needed: Fuel consumed by SGIP generator Net electricity produced by SGIP generator (interval data) Useful thermal energy recovered (for CHP systems)
Metered data sources: Host sites, project developers, utilities Third party providers
Performance data providers (PDPs) emerging in SGIP Itron installed metering (on behalf of PAs)
Net electricity (over 190) Useful thermal energy (over 120)
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Data Collection for Impacts Evaluation Not a one time process
Data collected on an on-going basis throughout the preceding year
Data collection and processing Converting multiple sources of data in different formats to
common formats Time/date stamp alignment
Site-Level
QA/QC
Site Inspection Reports
Monitoring Plans
Weather Data
Electrical, Thermal, Fuel Raw Interval Data
Data validation When does zero mean zero
generation vs no communication? QA/QC
Verifying that values “look” correct
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SGIP: A Closer Look at Operational Status SGIP represents legacy projects installed over the past eleven years and newer projects Important to distinguish “on-line” versus decommissioned projects
Decommissioned defined as equipment has been out of service and removed from the site On-line projects may be temporarily down at times Not always able to accurately identify decommissioned projects Loss of contacts and reporting from older projects leads to “unknown” designations
Technology
On-line Decommissioned Unknown
No. of Projects
Rebated Capacity
(MW)
Percent Total
Rebated Capacity
No. of Projects
Rebated Capacity
(MW)
Percent Total
Rebated Capacity
No. of Projects
Rebated Capacity
(MW)
Percent Total
Rebated Capacity
IC Engines 176 115.4 62% 33 14.9 76% 46 25.9 57%
Fuel Cells 109 28.6 15% 6 1.3 6% 16 8.4 19%
Gas Turbines 7 24.5 13% 0 0 0 1 1.2 3%
Microturbines 92 18.3 10% 21 3.4 17% 27 3.1 7%
Wind 0 0 0 0 0 0 10 6.8 15%
Total 384 186.8 100% 60 19.6 100% 100 45.3 100%
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SGIP: Capacity and Utilization Capacity reflects program participation
Enables measurement of trends by technology, fuel, etc. Utilization reflects use of capacity
Critical in assessing impacts Also provides valuable information on aging trends
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Examples of Trending with Utilization and Capacity
Utilization trending can help identify how project age affects capacity factor Figure at left shows clear increase in off-line capacity with age and associated
decline of average annual capacity factor Capacity trending can show impacts due to capacity changes
Graph at right demonstrates how lower growth in IC engine capacity affected annual energy delivery from IC engines over time
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Treatment of Calendar vs Year in Operation (Age) Calendar year provides information that allows year to year comparisons and
trending Figure on left shows annual capacity factor trends by year
Year in operation (year) provides information on how performance of technologies vary with time in the field Figure on right shows changes in capacity factor as the technology ages
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SGIP: Annual Energy Impacts Annual energy impacts
estimated at different levels and timeframes: Program-wide and at
Program Administrator level
Broken out by technology and fuel type
By quarter and annual Trended over time
Can be by technology or portfolios
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SGIP: Peak Demand We look at peak impacts at
various levels CAISO system demand
Summer peak Impacts at top 210 hours
Utility system peak demand Peak at distribution feeders Peak at customer site
Intent is to determine influence of SGIP technologies on resource adequacy Are SGIP DG technologies
available when needed? Assess using hourly capacity
factors during peak
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SGIP: Transmission and Distribution System Impacts With increasing amounts of DG
capacity projected for the future, peak impacts occurring below the CAISO and utility peak demand become more important Began examining DG
generation impacts on distribution feeder peaks
Significantly different investigation
Findings: DG can help unload
distribution feeder peaks Unloading impact tied to DG
capacity and may become more pronounced with increasing amounts of DG
DG impacts tied to feeder characteristics (e.g., customer mix, length, etc)
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SGIP: Optimizing DG Dispatch Feeder studies showed DG
can help unload distribution system Occurred haphazardly;
without design by project or utility
Shown by example in top figure
Can DG resources be operated to meet both needs of site and utility? Led to study on optimizing
dispatch and location of DG resources under the SGIP
Bottom figure shows how load following generator can help address feeder demand
Same demand curve
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SGIP: Optimizing DG Dispatch (cont’d) Affects of blending multiple
DG resources? Looked at same
representative feeder with intermittent PV and multiple load following DG
Multiple DG not only addresses feeder demand but firms intermittent PV
Created representative “look-up” tables
Full set of results in topical report: “Optimizing Dispatch and
Location of Distributed Generation”
Same demand curve
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SGIP: Combined Heat & Power Efficiencies CHP makes up an increasing amount of SGIP capacity Important to determine efficiencies
Useful thermal energy efficiency Overall system efficiency
𝑈𝑠𝑒𝑓𝑢𝑙 𝐻𝑒𝑎𝑡 𝐶𝑜𝑛𝑣𝑒𝑟𝑠𝑖𝑜𝑛 𝐸𝑓𝑓𝑖𝑐𝑖𝑒𝑛𝑐𝑦= 𝑈𝑠𝑒𝑓𝑢𝑙 𝐻𝑒𝑎𝑡 𝑅𝑒𝑐𝑜𝑣𝑒𝑟𝑒𝑑𝐹𝑢𝑒𝑙 𝐼𝑛𝑝𝑢𝑡 (𝐿𝐻𝑉) 𝐸𝐶𝐸= 𝐸𝑙𝑒𝑐𝑡𝑟𝑖𝑐𝑎𝑙 𝑂𝑢𝑡𝑝𝑢𝑡𝐹𝑢𝑒𝑙 𝐼𝑛𝑝𝑢𝑡 (𝐿𝐻𝑉)
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SGIP: Useful Thermal Energy Investigated applications
for thermal energy The majority of projects
recovered waste heat to offset boilers
However, a significant amount of CHP capacity used recovered energy for combined heating and cooling
Electric only DG technologies have emerged in recent years
Useful waste heat recovery rates vary by building type also
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SGIP: Overall System Efficiencies Non-renewable CHP
systems must achieve a high overall system efficiency to achieve GHG benefits Represents sum of
electrical and thermal energy efficiency
Several observations: Gas turbines achieved the
highest system efficiencies, followed by IC engines
All electric fuel cells achieve modest system efficiencies
Realizable useful thermal efficiencies dependent on thermal loads at host sites and coincidence to electrical loads
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SGIP: Trending of Electrical and Thermal Energy We examined delivery of energy by electricity and thermal from inception of the SGIP going
forward Interestingly, fuel cells have increasing capacity and associated electricity delivery but provide
little thermal energy delivery We’re seeing growth in fuel cell capacity. Most of emerging fuel cell capacity tied to all electric
fuel cells. Implications to GHG aspects?
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SGIP: Greenhouse Gas Emissions A primary goal of
SGIP is to achieve net GHG emissions reductions (relative to baseline use) Reductions tied
to: Electrical load Heating load Cooling load Also affected
by use of renewable fuels
Estimates based on 8760 hour per year treatment
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SGIP: GHG Emissions from Non-Renewable CHP Electricity:
Baseline: CA mix of resources and GHG from E3 calculator
SGIP: generated electricity on 8760 basis
Heating: Baseline: boiler fuel used on-
site SGIP: useful waste heat is
assumed to offset boiler fuel Cooling:
Baseline: on-site cooling from electric chillers
SGIP: useful waste heat directed to absorption chillers
Observations: Fuel cells and gas turbines
showed net GHG emission reductions for non-renewable CHP
What is happening and why?
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SGIP: CHP Electrical Efficiency & GHG Emissions SGIP net GHG emissions driven by
several factors: CA electricity mix
Historically driven by mostly natural gas fueled central station systems– Most of the year, the grid
supplies electricity from efficient (45% plus) combined cycle systems
– During peak (< 500 hrs per year) is generated from older, less efficient (30-35%) combustion turbines
SGIP CHP resources With exception of fuel cells,
SGIP CHP have low electrical efficiency– Can’t “beat” combined cycle
for most of the year on an efficiency basis
– Results in grid having lower GHG emissions than SGIP generator
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SGIP: Thermal Efficiency & GHG Emissions Except for all electric fuel
cells, non-renewable CHP can’t rely on electrical conversion efficiency to obtain net GHG reductions Instead, must rely on useful
heat recovery to obtain net GHG reductions
Examined SGIP CHP historical useful heat efficiencies
Compared to theoretical useful heat recovered needed to obtain net GHG reductions In general, non-renewable
CHP must consistently have higher than observed useful waste heat recovery to achieve net GHG emission reductions
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2030 technical potential
Source: ICF
SGIP: Looking to the Future (CHP)
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These are the greatest areas of CHP potential in the industrial sector at 2030• Chemicals and food industries represent
over 1,300 MW in CHP sizes up to 5 MW• Over 700 MW of potential in the 5 – 20
MW range
Smaller scale CHP has good potential across the commercial sector• Commercial buildings, hotels, hospitals and
govt buildings represent over 3,000 MW of potential capacity in CHP sizes up to 5 MW
• Universities have over 500 MW of technical capacity at sizes larger than 5 MW
SGIP: Getting to There from Here (CHP)
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Meet the CARB Scoping Plan GHG target for CHP• 6.7 MTons of GHG
reductions by 2020• Be cost effective
GHG methodDevelop DG/CHP that is responsive to utility and customer needs• Provides ramping
as needed• Cost effective peak
relief measure• Helps firm the
electrical grid
Capacity Growth is Only One Goal
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Decisions being made now are fashioning the future grid
Growth of DG and CHP
Significant Reductions in GHG Emissions
Interconnection of intermittent renewables
Increasing and Competing Demands in the Next Decade
50% of RPS interconnected by 2013; 65% by 2016; and 75% thereafter
6.7 million metric tons from CHP alone by 2020
12,000 MW of DG and 6,500 MW of CHP by 2020
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How CHP systems respond to thermal or electrical demand can affect GHG emission outcomes
Mixed GHG reductions
Consistent GHG reductions
Many Peak Demand Targets
High Volatility When Unplanned
GHG Emissions Peak Demand
DG and CHP projects currently target customer demand; not utility demand. Left unplanned, future DG & CHP projects may exacerbate peak demand and congestion issues
How to realize these benefits
from mixing and blending projects
Begin by examining site electrical and
thermal demands
among high potential end
uses
Currently, Conflicting Results from SGIP Projects
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Smaller scale CHP has good potential across the commercial sector• Commercial buildings, hotels, hospitals and
govt buildings represent over 3,000 MW of potential capacity in CHP sizes up to 5 MW
• Universities have over 500 MW of technical capacity at sizes larger than 5 MW
We have 8760 hourly electrical and thermal demand profiles for each of these commercial end uses based on SitePro
We can use these profiles to determine:• Sizing to meet thermal demand
and reduce GHG emissions• Sizing to meet on-site electrical
demand that does not lead to thermal dumping
• Identification of possible electricity export to the grid
Investigating High Opportunity Approaches
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“Peak” electrical demand for 13 hours(7 am to 8 pm) ranging from approximately 250 kW to 350 kW
Targeting this electrical load with a self generator could help offset the hospital’s peak demand over typical summer weekdays
14 hrs duration ~ 350 kW
Electrical Demand: Inland Hospital Summer Weekdays
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This is the hospital’s thermal load that could be offset using waste heat recovery from a CHP system. Note that only thermal uses are offset (i.e., cannot offset cooking from natural gas with CHP)
15 hrs duration
A minimum of 1 million Btu/hr of thermal demand for 15 hours(5 am to 8 pm)
~ 1 MM Btu/hr
Thermal Demand: Inland Hospital Summer Weekdays
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If an ICE CHP system is used to meet the 1 MMBtu/hr thermal demand at the hospital, a heat recovery rate of at least 4 kBtu/kWh is needed to achieve GHG reductions.• Generator = (1,000 kBtu/h)/4 kBtu/kWh • Generator = 250 kW
15 hrs duration
From earlier work, we know that heat recovery rates between 2 to 6 kBtu/kWh are needed to achieve GHG reductions for non-renewable CHP systems.
GHG reductions can be achieved at realistic heat recovery rates
Example of Optimizing GHG Reductions
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15 hrs duration14 hrs duration 250 kW CHP system for thermal and some
electrical needs
To optimize GHG reductions, we set the CHP system to recover 4 to 5 MBtu per kWh of generated electricity. Per our example, to ensure consistent recovery of 1 MM Btu/h of thermal energy using 4 MBtu per kWh, this could mean using an ICE CHP generator capacity of 250 kW.
100 kW fuel cell for remaining electrical needs
Note that this also provides the customer site with 250 kW of “peak” electricity that does not have to be procured and delivered by the utility. However, a 250 kW CHP system does not fully meet the electrical needs of the site. An all electric fuel cell with a rating of up to 100 kW could provide the remaining electrical need and not increase GHG emissions (i.e., no thermal dumping of waste heat that could not be used by the site).
Matching Electrical to Thermal Demand: Inland Hospital Summer Weekdays
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16 hrs duration
“Peak” electrical demand for 16 hours(6 am to 10 pm) ranging from 125 kW to 250 kW
Targeting this electrical load with a self generator could help offset the hotel’s peak demand over typical summer weekdays
~ 250 kW
Hotels are another example of a high potential end use
Electrical Demand: Inland Hotel Summer Weekdays
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15 hrs duration
This is the hotel’s thermal load that could be offset using waste heat recovery from a CHP system. Note that only thermal uses are offset
A minimum of ~ 600,000 Btu/hr of thermal demand for 15 hours(5 am to 8 pm)
~ 600,000 Btu/hr
Thermal Demand: Inland Hotel Summer Weekday
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16 hrs duration
15 hrs duration
To optimize GHG reductions, we set the CHP system to recover 4 to 5 MBtu per kWh of generated electricity. To ensure consistent recovery of 600,000 Btu/h of thermal energy using 4 MBtu per kWh, this could mean using an ICE CHP generator capacity of 150 kW.
100 kW fuel cell for remaining
electrical needs
150 kW CHP system for thermal and some electrical needs
Note that this also provides the customer site with 150 kW of “peak” electricity that does not have to be provided by the utility. However, a 150 kW CHP system does not fully meet the 250 kW electrical needs of the site. An all electric fuel cell with a rating of up to 100 kW could provide the remaining electrical need and not increase GHG emissions (i.e., no thermal dumping of waste heat that could not be used by the site)
Matching Electrical to Thermal Demand: Inland Hotel Summer Weekdays
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14 hrs duration17 hrs duration
15 hrs duration 15 hrs duration
Winter electrical demand is 50% of summer demand but more consistent and of longer duration
Winter thermal demand (magnitude and duration) is about the same as the summer demand but more consistent
This suggests that the CHP unit be sized to meet the thermal demand and meet lower electrical demand to be operated year round. Use of an all electric fuel cell would be limited to meeting increased hospital demand during the summer and could provide export during winter.
What About Differences Between Summer and Winter Demands?
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However, this doesn’t address responsiveness for utility needs; must also balance electrical generation with distribution and transmission needs. Possible interplay of DG within microgrid settings.
Achieving Simultaneous GHG and Responsiveness BenefitsRequires:
- Thermal and electrical demand profiles (8760 profiles ideally)
- Balancing of thermal and electrical loads - May require multiple generation systems to achieve GHG reductions and peak relief
Establish GHG Baseline
Identify: - Minimum thermal demand across largest duration
- Extent to which thermal demand varies (ramping) - CHP heat recovery rate needed to achieve GHG reductions (based on technology)
Size Electrical Developed on: - Electrical generation tied to thermal load - Any additional generation needed to meet customer electrical demands - Identification of amount and timing of any generation that has potential for export to grid
Summary of Matching Electrical and Thermal Demands to Coordinate Benefits