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Is CHP Right for Me?. New York State Energy R & D Authority Addressing Energy, Economic, and Environmental Priorities. What is DG? What is CHP? Benefits of DG/CHP. Available technologies/equipment. Issues/hurdles for implementation. Overview. Electric power generation close to the load. - PowerPoint PPT Presentation
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New York State Energy R & D Authority
Addressing Energy, Economic, and Environmental Priorities
Is CHP Right for Me?
Overview
• What is DG?
• What is CHP?
• Benefits of DG/CHP.
• Available technologies/equipment.
• Issues/hurdles for implementation.
What is Distributed Generation?
Electric power generation close to the load.
• Small-scale relative to central-plants.
• Can use fossil fuel – natural gas, diesel, propane…, or renewable energy – solar, wind, landfill/digester gas…
DG Applications
• Premium Power – reliability, power quality.
• Backup Power – reliability.
• Peak Shaving – peak demand reduction.
• Base Load/CHP – cost reduction.
Combined Heat and Power (CHP)
CHP: Onsite coincident production and use of electrical or mechanical power and thermal energy.
DG/CHP
Peak ShavingMicro-turbine
Residential Fuel Cell
CommercialIC Engine
CommercialBP Steam Turbine Boiler
Power Combined Heat & Power (CHP) Heat
Distributed Generation (DG)
Where Does DG/CHP Make Sense?
• Capacity constrained, high electric demands.
• High thermal (steam, hot water, direct heat, cooling) demands.
• Coincident thermal and electric demands.
• Extended operating hours.
• Access to fuels (byproducts, natural gas).
Benefits of DG/CHP
• Fuel “in” at one place, multiple benefits “out” yields financial savings.
• Diversification of energy supply sources yields greater reliability ====> Energy Security.
• Return on investment:
DG/CHP ====> every day.
Emergency generator ====> sporadically.
Fuel “in” at one place,multiple benefits “out”
COOLING:Air Conditioner.
HEATING:Defroster.
POWER (Electrical):AlternatorGenerates DC Power.
POWER (Locomotion):Mechanical (Rotary)Shaft Power.
Fuel “in” at one place,multiple benefits “out”
DG-CHP Generating Options
Micro-TurbinesInternal Combustion Engines
Gas Turbines
Fuel Cells
Steam Turbines
Choice of Equipment
• First: identify your electric & thermal needs.
• Next: match needs to a type of technology. Example: Engine - versus - Microturbine
Electrical efficiency: Engine ~ 35%, Microturbine ~25%
Byproduct heat: Engine high- & low-grade, Microturbine all high-grade
Other considerations: familiarity of technology, dump radiator, emissions
• Finally: select an equipment vendor.
Evolving Equipment
• Pre-engineered skid-mounted systems.
• A fully-integrated car produced on an assembly line is likely to be more reliable, less expensive, and “running” sooner than buying the individual parts and having someone assemble it for you.
• Likewise with CHP (not quite “plug-and-play” yet).
• Major efforts by USDOE recently.
DG/CHP Issues/Hurdles
• Interconnection with utility grid/tariffs.
• Synchronous - versus - Induction.
• Air permit.
• Footprint/available space.
• Financing.
Load Profiles
• Coincident thermal and electric demands.
Daily load profile
Electric
Thermal
Midnight Noon Midnight
En
ergy
Dem
and
Load Profiles
• Seasonal variations.
Month -by- month load profile
Electric
Thermal
January June July December
En
ergy
Dem
and
Load Profiles
• Load shaping via absorption cooling.
Month -by- month load profile
Electric - w/ AC
Electric - w/o AC
Thermal - w/ AC
Thermal - w/o AC
January June July December
En
ergy
Dem
and
Capacity Factor
DG Electric Power Generation Costs
0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1
Capacity Factor
Gen
erat
ion
Co
st (
$/kW
h)
Capital Cost Fuel Cost O&M Cost Total Cost
CF = 1100% output for 100% of time
CF = 0.75100% output for 50% of timePlus50% output for 50% of time
CF = 0.5100% output for 50% of time
CF = 0.550% output for 100% of time
CF = 0.3100% outputfor 10 hours/day (8am – 6pm)for 5 days/week (M-F)for 52 weeks/year
Electric Load Profile
Daily load profile
Ele
ctr
ic D
em
an
d
Midnight Noon Midnight
Electric Load Profile
Daily load profile
Ele
ctr
ic D
em
an
d
Midnight Noon Midnight
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Electric Load Profile
Daily load profile
Ele
ctr
ic D
em
an
d
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Electric Load Profile
2,000 4,800 8,760500
Ele
ctri
c D
eman
d
There are 8,760 hours per year
Do the Easy Things First
Weatherization
Energy Efficient Lighting
Programmable Controls & Thermostats
CHP
Energy Star Appliances
NYSERDA Funding Programs
• Energy Audits which include ‘quick screen’ for CHP.
• Site-specific CHP feasibility studies.
• CHP hardware installation.
Quick Screening for CHP
• There are various quick screening tools in development or use by NYSERDA, local gas utilities, & UMASS Amherst.
• The NYSERDA tools are typically incorporated into a more comprehensive energy efficient scope of work.
• Generally they analyze the cost-effectiveness of CHP to determine whether a building should pursue a detailed feasibility study.
R&D to Implementation - AMP
• The Assisted Multifamily Program provides whole-building energy efficiency to low- to moderate-income properties of > 4 units.
• AMP provides a complete energy assessment, financial packaging including a NYSERDA grant, & construction oversight, in addition to 3-year monitoring & consumption analysis.
R&D to Implementation - AMP
• CHP must be considered by the auditor as a program requirement using the quick screening tool.
• If the analysis warrants it, the cost for a feasibility study AND an installed CHP system are packaged into the overall deal.
R&D to Implementation - AMP
• If a viable financial package cannot be reached, AMP will consider additional funding from the CHP PON administered by R&D, otherwise the costs are borne by the owner and AMP.
• AMP typically packages deals at a 4:1 ratio of owner investment to NYSERDA funds.
Current Projects
Chart does not include Co-op City CHP project at a cost of $7.5 million with an SIR = 5.5.
AMP Quick Screening Tool Project Characteristics
$0.00
$100,000.00
$200,000.00
$300,000.00
$400,000.00
$500,000.00
$600,000.00
$700,000.00
$800,000.00
Est
imat
ed C
ost
0.00
1.00
2.00
3.00
4.00
5.00
6.00
7.00
8.00
Sav
ings
-to-In
vest
men
t R
atio
Current Projects
• Systems are sized to maximize needs & restrictions related to the electric peak & baseload as well as the daily peak DHW load using additional DHW storage if necessary.
• Estimated savings range from 9,232 to 52,002,000 kWh annually.
• Majority of systems are 30-60kW systems.
AMP Screening ToolElectric Data (This data is required for any analysis.) Thermal Data Data required.
Peak Total MonthlyEnergy-
based Cost Load oilMonthly Bill
Including Average Demand Usage Bill Factor Consumed Taxes Cost
Month Year kW kWh $$ $/kWh % Year mmBTU(DT) $$ $/mmBTUJan 2003 227.0 74,792 10,280 0.137 45% 2003 2,872 20,377 7.09Feb 2003 232.3 67,976 10,957 0.161 40% 2003 2,511 21,811 8.69Mar 2003 227.0 64,376 10,815 0.168 39% 2003 1,203 5,279 4.39Apr 2003 234.7 69,416 12,345 0.178 41% 2003 1,768 8,652 4.89May 2003 227.0 68,072 11,179 0.164 41% 2003 402 2,045 5.09Jun 2003 402.2 99,368 18,473 0.186 34% 2003 965 4,761 4.93Jul 2002 417.6 150,824 22,558 0.150 49% 2002 - -
Aug 2002 395.5 141,896 21,390 0.151 49% 2002 - - Sep 2002 344.6 103,256 15,096 0.146 41% 2002 565 3,126 5.54Oct 2002 295.2 71,336 10,374 0.145 33% 2002 1,469 8,429 5.74Nov 2002 233.3 79,544 10,696 0.134 47% 2002 1,480 7,990 5.40Dec 2002 234.7 70,904 9,882 0.139 41% 2002 2,564 16,237 6.33
Annual quantities: 418 1,061,760 164,044 0.155 29% 1,317 8,226 6.25Monthly Averages: 289 88,480 42% Efficiency of current equip: 75%
Auditor enters consumption & utility data into the tool.
AMP Screening Tool
Cost-effectiveness of the project based on electric load, DHW load, & selected CHP equipment.
Equipment Selection Operation Economic Assumptions Choose Machine: Contract Term: years
Manufacturer= Coast Intelligen Sales Tax: 8.25%Model = 55 IC (On equipment only)
Capacity= 55 kW
SizingNumber of Machines: 1
System Capacity = 55 kWAs Fraction of Peak = 13% Special Gas Price: 10.00$ /mmBtu(DT)
As Fraction of Baseload = 52% (Including all taxes)
Preliminary and Tentative Cost and Savings Estimates AssessmentCost/month Installed Cost 103,000
Purchased Generated Consumed $savings/year 30,017 Current BAU: 13,670$ 0.1545$ 0.1545$ Pay Back (years) 3.4 With self generation: 11,169$ 0.1545$ 0.0909$ 0.1262$ Savings to Investment Ratio 4.2 Savings = 18.3% 18.3% $Life Cycle Savings 331,444
Cost per kWh
Coast Intelligen 55kW 5Baseload
Peak Shaving
Select Self Gen Gas PriceCurrent Gas Price (above)
Special Gas Price (below)
Testing & Verification
• The current AMP quick screening tool is being applied retroactively to some of our multifamily CHP projects to test its accuracy.
• A continuing analysis will be conducted in each AMP project to compare the tool’s projections to those of the eventual feasibility study and ultimately to actual performance of installed projects.
$300,000 DOE Funding for NERAC
Northeast Regional Combined Cooling, Heating and Power Applications Center
Mission: Facilitate the technology transfer and deployment of advanced CHP.
Region: 7 state region of Northeast USA.
Services: Education, outreach, and technical assistance.
Constituency: CHP for both buildings and industrial settings.
Guidance: State Advisory Board, NECHPI.
DOE Funding$300,000
Center Co-DirectorshipsPace Energy ProjectUMass Center for Energy Efficiency and Renewable Energy
Special Projects in New York - FY 2003
www.northeastchp.org
www.eere.energy.gov/de/technologies/euii_chp_app_rac.shtml
NYSERDA Funding Programs
• Energy Audits which include ‘quick screen’ for CHP.
• Site-specific CHP feasibility studies.
• CHP hardware installation.
PON 831 CHP & Renewable Generation Technical Assistance
• Competitive Solicitation
• $250,000 in available funding
• 50% cost share up to $50,000
• December 1, 2004 Deadline
Limitations
• Study must include heat recovery
• At minimum, 75% of electricity generated would be used on-site
• 20 MW capacity for CHP applications
Study Components
• Load profile analysis
• Determination of CHP efficiency
• Site information
• Economic evaluation
• Tariff impacts and interconnection issues
• Permitting
• Reliability
Load Profile
• Detailed analysis of load profiles– What are the thermal demands of the heat
sinks?– When is the heat used?– Are the thermal and electrical loads
coincidental?
Load Profiles
• Seasonal variations.
Monthly load profile
Electric
Thermal
January June July December
En
ergy
Dem
and
Load Profiles
• Coincident thermal and electric demands.
Daily load profile
Electric
Thermal
Midnight Noon Midnight
En
ergy
Dem
and
System Efficiency
• Annual Thermal utilization
• Annual fuel conversion efficiency
Heat recovered + Electricity generated
Fuel input
• NYSERDA target is 60%
Site Information
• Floor Plan
• Fuel requirements/ availability
• Construction schedule
• Existing air permit
Economic Evaluation
• Life Cycle Cost analysis
• Operational costs– Maintenance– Tariff impacts
• Detailed capital cost breakdown
Tariff Impacts & Interconnection
• Impact of CHP on existing tariffs– For example CHP exemption in ConEd territory
• Detailed discussion of any new applicable tariff impacts
• Grid interconnection issues– Standard interconnection under 300kVa
Permitting
• Environmental permits– EPA– DEP– DEC
• Detailed emission inventory
• Building permits– Special fuel line requirements
Reliability & Availability
• Estimated downtime – Scheduled – Unplanned
• Affect on customer’s core business
Example
• Large NYC hospital
• 7.5 MW gas turbine
• $4,000,000 annual savings
• $20,000,000 estimated installation cost
• 75% Annual Fuel Conversion Efficiency
• 37,500 pound reduction of NOx
NYSERDA Funding Programs
• Energy Audits which include ‘quick screen’ for CHP.
• Site-specific CHP feasibility studies.
• CHP hardware installation.
NYSERDA Budget$200 Million Per Year
Pay To The Order Of: Your Name Here
One-Million Dollars
NYSERDA
$1,000,000
Not negotiable
Objectives of DG/CHP Program
• Support CHP to bolster NYS economy.
• Encourage clean and efficient systems.
• Establish a broad portfoliovarious technologies, various end-use sectors.
Document hurdles and lessons learned:
• Identify “Role Model” systems ====> replicate: faster, better, cheaper.
Annual Competitive Solicitation PON # # Proposals # Proposals NYSERDA Funds (date closed) Received Selected Earmarked
PON 554 @ 10/26/2000 36 16 $4 Million--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
PON 536 @ 5/31/2001 55 36 $18 Million--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
PON 669 @ 3/12/2002 112 45 $20 Million--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
PON 750 @ 4/16/2003 66 20 $11 Million--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
PON 800 @ 4/20/2004 60 39 $11 Million--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Total to Date 329 156 $64 Million
Leveraging almost $250 Million of proposers’ funds
Competitive Selection
$
GoodCoincidence of
Electric/ThermalDemand at Site
Good“Societal”Benefitsbeyond
Site
GoodLogistics
at Site
Most DeservingOf Public Funds
Certain End-Use Sectorsbased on Best Professional Judgment
Load Pocket
Empire Zone
Brownfield
New Lessons
FuelAvailability
etc.
Market Opportunity for CHP in NYS
Forecasted new CHP over the next decade:
• “Technical Potential” scenario
8,500 MW at ~ 26,000 sites
(99% of these sites sized
at 5 MW or smaller)
• Base-case scenario
746 MW at ~ 2,000 sites
• Accelerated-case scenario
2,200 MW at ~ 6,000 sites
0
10
20
30
40
50
60
70
80
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
En
erg
y S
av
ing
s -
- tr
illio
n B
tu/y
ea
r
Business-as-Usual
Accelerated
Study at www.nyserda.org/dgchp.html
DG/CHP Case Studies
• Residential buildings:
Brooklyn, Manhattan
• Commercial building:
Waldbaums Supermarket
Remaining CHP Technical Potential
• Multiple Stakeholders– Building Owner / Cooperative (Board), Tenants,
Utility, Design Engineer, Developer, Oversight Agencies, Local Code Enforcement, Financing Institution.
• Large Base of Existing Older Buildings– Limited space within the building– Usually located in a densely populated area
– 2/3 of all apartments in NY State are in NYC– Residents more sensitive to noise, vibration and service
interruptions.
Challenges
Metering and Cogeneration
Direct Metered – Each apartment in the building has a electric utility meter, and the individual purchases and pays for their own electricity.
• Promotes energy efficiency as consumers incur the cost associated with their energy use.
• Load is not available to being supplied by on-site generation and hence limits the application of CHP.
Mastered Metered – One electric utility meter for the entire residential building.
• Entire building’s electric load is available to Cogeneration.
• Tenants less likely to be energy conscious.
Sub-Metered Master Building – Tenants pay for the the electricity they use and the entire building’s electric load is available to cogeneration.
MULTIFAMILY BUILINGS – SeaRise I & II, Brooklyn
Site Characteristics: Low Income Housing, 2 Buildings, 334 Apartments Each, Master Metered
Technology: IC Engines (Two 55 KW Coast Intelligen Cogen Units per Bldg.)
Operating Mode: 24/7, Grid-Interconnected, Operating on Natural Gas
Recovered Thermal Energy Use: Domestic Hot Water
Benefits: Expected net annual utility cost reduction of $65,000 (Payback ~ 6 yrs)
Results to Date: System Installed and in the process of be Commissioned
1987 SeaRise I & II installs Cogeneration System• IC Engine 145 kW (restricted to 120 kW), thermal output 830,000 Btu/Hr, thermal storage – 1200 gallons, operating strategy – thermal, thermal load – DHW
Experienced reduced operation due to low thermal demand (no dump radiator).
Extended outages• Engine failure due to poor unit reliability
• Equipment manufacturer filing for bankruptcy
• Lack of a maintenance contractor
• Local personnel had little or no involvement with the units other than to inform maintenance contractor when unit was out of service.
Site History
Instrumentation should be installed to measure electric and thermal loads before sizing the cogeneration system;
Units sized to meet 50 to 75 percent of the peak DHW thermal load with appropriately sized thermal storage will achieve near-continuous operation. Dump radiators, if economically justified, will also improve unit operations and reliability in some cases;
Lessons Learned
Sizing cogenerators to supply both DHW heating and significant portions of site space heating will result in grossly oversized unit during the five to six months when space heating is minimal. Multiple unit installations and/or dump radiators can be used to reduce unit start/stop cycling if they can be economically justified;
Lessons Learned (continued)
Cogenerators should be specified that have proven track records for dependable operation. Consideration should be given to the manufacturer’s support staff and facilities that will be available to support the unit after installation;
Installation of a remote monitoring system is recommended to provide automatic notification of the system outages and to assist in troubleshooting cogenerator problems;
Lessons Learned (continued)
Effective use of on-site personnel in the daily operation of the cogenerator results in reduced outage time;
Service agreements covering both cogenerator and balance of plant equipment should be in place at the time of installation. If possible, a single contractor should be responsible for maintaining both cogenerator and balance of plant equipment.
Lessons Learned (continued)
MULTIFAMILY BUILINGS – 10 West 66 Street, Manhattan
Site Characteristics: Electrically heated and cooled multifamily (256 units) residential cooperative building, gas fired hot water system, Master Metered w/ sub-metering.
Technology: one 70 kW Ingersoll-Rand Microturbine + 100 kW Gas Recip Engine Standby/Backup DG unit
Operating Mode: 24/7, Grid-Interconnected, Operating on Natural Gas
Recovered Thermal Energy Use: Domestic Hot Water
Benefits: Expected net annual utility cost reduction of $36,000 (Payback ~ 9 yrs)
Results to Date: System Installed and Running
MULTIFAMILY BUILINGS – 205 West End Avenue, Manhattan
Site Characteristics: 540 unit Cooperative, Heating & Hot Water Con Ed Steam, Master Metered w/ Sub-metering
Technology: 2 – 150 KW Waukesha VSG11GSID continuous duty reciprocating engines
Operating Mode: 24/7, Grid-Interconnected, Operating on Natural Gas
Recovered Thermal Energy Use: Domestic Hot Water, Comfort Heating
Benefits: Expected net annual utility cost reduction of $319,500 (Payback ~ 2.2 yrs)
Results to Date: System Installed and Running
Unbiased Feasibility / Engineering Study• Technology, Size and System Operation matches the facility
characteristics and needs.
Verify Contractor and Equipment Performance
Staged Implementation for Projects with Multiply Buildings within a Complex• Get the bugs out before replicating.
Suggestions for Minimizing Risk
DG/CHP Case StudyWaldbaums Supermarket
DG/CHP Case StudyWaldbaums Supermarket
Total Store Power - 09/15/03
22: 0: 2: 4: 6: 8: 10: 12: 14: 16: 18: 20: 22: 0:
14 15 16
September
0
100
200
300
400
500P
ower
(kW
h/h)
Total (Utility Import + Turbine Output)Utility ImportTurbine Output
Peak Total Demand: 395.5 kW @ 12:15 PM
Peak Utility Import Demand: 342.5 kW @ 12:15 PM
Total Load: 7811.9 kWh
Utility Energy Purchased: 6494.5 kWh
Energy Generated: 1317.4 kWh
DG/CHP Case StudyWaldbaums Supermarket
Gas Furnace
Heating HR Coil
Supply Fan
DX Coil
Supply Air Return
Air
Regen HR Coil
Gas Burner
Regeneration Inlet
Compressors
Des Wheel
MicroturbineHeatExchanger
Useful Heat
Electricity
Fuel
Exhaust
Exhaust
DG/CHP Case StudyWaldbaums Supermarket
[1] [2] [3] [4] [5] [6] [7] = [1-3] / [2] [8] =
Turbine Parasitic Loads [1-3-4+5+6] / [2]
Power Output Gas Input
Gas Compressor
Heat Recovery
Glycol Pump
Space Heating
Desiccant Regen
"Net" Turbine
Generation Efficiency
"Net"CHP
Efficiency
% of Month in
OperationDate (kWh) (MBTU) (kWh) (kWh) (MBTU) (MBTU) (%) (%)April-03 15,356 209,649 1,097.3 250.0 16,162 0 23.2% 30.5% 39%May-03 30,414 411,031 2,113.0 474.6 29,084 2,045 23.5% 30.7% 73%June-03 39,087 549,741 2,767.1 530.1 18 17,223 22.5% 25.4% 99%July-03 39,185 568,723 2,878.3 635.8 103 72,102 21.8% 34.1% 100%August-03 10,864 161,883 838.9 185.7 0 46,035 21.1% 49.2% 29%September-03 22,210 328,755 1,627.2 359.1 457 40,837 21.4% 33.6% 58%October-03 33,777 465,929 2,312.4 512.2 21,063 12,828 23.0% 29.9% 80%November-03 10,005 138,575 693.8 153.3 5,939 6,192 22.9% 31.3% 25%December-03 5,290 66,833 370.7 81.7 4,688 0 25.1% 31.7% 13%January-04 34,702 417,133 2,394.5 535.4 2,769 0 26.4% 26.7% 83%February-04 27,701 341,383 1,904.6 426.4 92,226 0 25.8% 52.4% 73%March-04 35,160 440,680 2,425.9 544.4 102,987 0 25.4% 48.3% 84%Year 303,749 4,100,315 21,424 4,689 275,496 197,263 23.5% 34.6% 63%
Heat Recovered
Note: Actual natural gas HHV is used.
DG/CHP Case StudyWaldbaums Supermarket
Economics: Strongly Linked to Fuel Cost
($10,000)
$0
$10,000
$20,000
$0.4 $0.5 $0.6 $0.7 $0.8 $0.9
Gas Commodity Price ($/therm)
Ne
t A
nn
ual
Sav
ing
s
Financing
• NYC Economic Development Corp
Energy Cost Savings Program (ECSP).
• Cash value of Emission Reduction Credits (ERCs).
• Business practices – Performance Contracting.
Financinghttp://www.newyorkbiz.com/Business_Incentives/Energy/
ECSPProgram.pdf
Benefits are available to businesses that generate their own electricity through distributed generation.
Rebate on “delivery charge” for natural gas used in CHP.
Rebate on “delivery charge” for grid-supplied electricity.
Rebate up to 4.44 cents per kWh self-generated via CHP.
Financing
Approved by NYPSC on March 20, 2003.
• Permits NFG to give customer funding to buydown cost of CHP equipment, lowering payback.
• Pilot program with initial term of 3 years. Annual cap of $1 million/year, total of $3 million.
• Proposed typical buydowns range $50,000 - $150,000. Actual buydown based on incremental margin per project.
• Customer must sign a performance contract with term of up to 6 years. May also be required to provide security.
national fuel DG Partnership Pilot Program
Financing
• NYC Economic Development Corp
Energy Cost Savings Program (ECSP).
• Cash value of Emission Reduction Credits (ERCs).
• Business practices – Performance Contracting.
Emission at the Central Power Plant
Emission from Conventional Heating
CHP efficiency is a key driver of the potential emissions benefit; less fuel burned means lower emissions (all else being equal)
Source: EPA CHP Partnership/Energy & Environmental Analysis, Inc.
Emission at the Central Power Plant
Emission from On Site Generation of Electricity
Heat
On Site Generation of Electricity
Emission from Conventional Heating
Lower Emissions than the Local Heat Plant
CHP vs. Conventional Generation emission comparisons can be viewed from three perspectives:
Total emissions: The total emissions of CHP vs. Conventional Generation to serve equivalent end-use needs (includes T&D losses).
Electric sector emissions: Comparison of the electric side emissions of CHP vs. Central Power Plant (includes T&D losses)
Thermal load emissions: Comparison of the thermal side of CHP vs. thermal side of Conventional Thermal Generation (i.e., the old boiler)
Emissions impacts for CHP depend on: (1) the CHP unit emissions, (2) the displaced/avoided grid emissions, (3) the retired/displaced on-site boiler, and (4) avoided T&D losses
Does CHP Lead to Reduced Emissions? It Depends.
Emission reduction credit (ERC). Any decrease in emissions of a nonattainment contaminant in tons per year, occurring on or after November 15, 1990:
(i) which is surplus, quantifiable, permanent, and enforceable; and
(ii) which results from a physical change in, or a change in the method of operation of an emission unit subject to Part 201 of this Title; and
(a) is quantified as the difference between prior actual annual emissions or prior allowable annual emissions, whichever is less, and the subsequent maximum annual potential; and(b) is certified in accordance with the provisions of section 231-2.6 of this Subpart; or(iii) which results from a physical change in, or a change in the method of operation of an air contamination source not subject to Part 201 of this Title, and is certified in accordance with the provisions of section 231-2.6 of this Subpart.
ERC Definitions per NYCRR 231.2(b)(14)
Clinton Hill
Apartments • Total Electricity Demand ~ 3,000 kW
• Annual Energy Costs before CHP- $ 1,500,000
• Annual Energy Savings with ~ 550 kW CHP ~ $260,000 per year
• Installation Cost ~ $1.4 Million
• Simple payback with CHP ~ 5 years
(without NYSERDA incentive)
• The project seeks to allow three 400HP residual oil fired boilers to be turned off in the summer by:
producing the entire hot water load for seven buildings with CHP. andsupplying a portion of the electric load with CHP.
• By turning off the boilers using ultra-low NOx microturbines, the project will be eligible for NY state Emission Reduction Credits.
NOx1.42 0.491
Situation Electricity PurchasedElectricity Generated
on SiteAdjustment for
T&D Loss NY Metro Plant
NOx On Site NOx
NOx Reduction due
to Cogen(MWh) (MWh) lbs lbs lbs tons lbs tons
Current 4,820 0 0% 6844 0 0 0 0 6844 3.4222Proposed 590 4,230 0% 838 2077 -17198 -15,121 -7.56 -14283 -7.14161
Net NOx Emissions -21128 -10.6
Fuel Nitrogen Content (%)
(MMBTU) (lbs/MMBTU) (lbs)Total 35,467 0.485 17198
Emission Reduction
NOx
# 6 OilThermal Energy Recovered
Clinton Hill Apartments - North CampusAnalysis of NOx Emission Levels
lbs/MWh
Boiler Performance
Overall Total NOx
0.5
Net Site
Ozone Attainment $/ton per yr Tons/Yr Dollar ValueNOx Severe 11,350$ 7.56 85,812 NOx Moderate 1,800$ VOC Severe 6,158$ 0 0VOC Moderate 1,500$ PM-10 -$ 3.333898 - CO2 2$ 272.5175 545 SOx -$ 45.34 - CO -$ 0.45 -
Total 86,357$
Potential Value of ERC'sClinton Hill Project 4/03
Financing
• NYC Economic Development Corp
Energy Cost Savings Program (ECSP).
• Cash value of Emission Reduction Credits (ERCs).
• Business practices – Performance Contracting.
FinancingPerformance Contracting
• Someone else pays for the equipment!
• You buy the “output” electricity and heat at a slightly reduced price than from elsewhere.
• Performance Contractor takes the financial risk, but reaps the majority of financial reward.
• Often, long-term contracts required.
Financing – Example at GRIA Design/Build
- On site CHP plants (two independent 750 KW natural gas generators).
- New absorption chiller.
- Various lighting and controls.
Project facts:
- $4.2 million project cost.
- No cost to County taxpayers or GRIA customers.
Monroe County Greater Rochester International AirportCombined Heat and Power Cogeneration Facilities
FinancingPerformance Contracting
Posted on: 08/21/2004 Publication date: 08/23/2004
Fitness Facility Uses Cogeneration
WALTHAM, Mass. — AmericanDG has agreed to supply low-cost energy to the Westfield Area YMCA in Westfield, N.J. The facility will receive a substantial portion of its electricity and hot water directly from an on-site, 150-kW cogeneration facility operated by AmericanDG. The system uses natural gas-driven cogeneration modules from Tecogen. Jim Lenox, director of facilities at the Y, stated, “Not having to make any capital equipment expenditure was an important factor in our decision.”
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