Final April, 2008
SRI/USEPA-GHG-QAP-44
April 2008
Test and Quality Assurance
Plan
OfficePower, Inc.
Elliott Microturbine DG / CHP Installation
Prepared by:
Greenhouse Gas Technology Center
Operated by
Southern Research Institute
Affiliated with the
University of Alabama at Birmingham
Under a Cooperative Agreement With
U.S. Environmental Protection Agency
and
Under Agreement With
\YSEHDA |yjew York State Energy Research and Development Authority
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Final April, 2008
EPA REVIEW NOTICE
This report has been peer and administratively reviewed by the U.S. Environmental Protection Agency, and
approved for publication. Mention of trade names or commercial products does not constitute endorsement or
recommendation for use.
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Final
April, 2008
Greenhouse Gas Technology Center
A U.S. EPA Sponsored Environmental Technology Verification ( ETr ) Organization
Test and Quality Assurance Plan
OfficePower, Inc.
Elliott Microturbine DG / CHP Installation
This Test and Quality Assurance Plan has been reviewed and approved by the Greenhouse Gas
Technology Center Project Manager and Center Director, the U.S. EPA APPCD Project Officer, and the
U.S. EPA APPCD Quality Assurance Manager.
Tim A. Hansen
Director
Greenhouse Gas Technology Center
Southern Research Institute
Date
Blair Martin
APPCD Project Officer
U.S. EPA
Date
William Chatterton
Project Manager
Greenhouse Gas Technology Center
Southern Research Institute
Date
Robert Wright
APPCD Quality Assurance Manager
U.S. EPA
Date
Eric Ringler
Quality Assurance Manager
Greenhouse Gas Technology Center
Southern Research Institute
Test Plan Final: April 2008
Date
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April, 2008
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TABLE OF CONTENTS
Page
LIST OF FIGURES i
LIST OF TABLES i
ACRONYMS AND ABBREVIATIONS ii
1.0 INTRODUCTION 1-1
1.1. PURPOSE 1-1
1.2. PARTICIPANTS, ROLES, AND RESPONSIBILITIES 1-1
1.3. TEST SCHEDULE 1-3
2.0 TEST PROCEDURES 2-1
2.1. TEST CONCEPTS AND OBJECTIVES 2-1
2.1.1. Controlled Test Period 2-1
2.1.2. Long-term Monitoring Period 2-2
2.1.3. Instrument Specifications 2-4
2.2. SITE-SPECIFIC CONSIDERATIONS 2-5
3.0 DATA QUALITY 3-1
3.1. DATA QUALITY OBJECTIVES 3-2
3.2. CALIBRATIONS AND PERFORMANCE CHECKS 3-3
3.3. AUDITS OF DATA QUALITY 3-4
3.4. INDEPENDENT REVIEW 3-4
4.0 ANALYSIS AND REPORTS 4-1
4.1. ELECTRICAL PERFORMANCE 4-1
4.2. ELECTRICAL EFFICIENCY 4-2
4.3. CHP THERMAL PERFORMANCE 4-2
4.4. ATMOSPHERIC EMISSIONS 4-3
5.0 REFERENCES 5-1
LIST OF FIGURES
Page
Figure 1-1 Test Participants 1-2
Figure 1-2 Test Schedule 1-4
Figure 2-1 Controlled Test Instrument Locations 2-2
Figure 2-2 Long-Term Monitoring Instrument Locations 2-3
Figure 2-3 Volumetric Flow Testing Location 2-4
LIST OF TABLES
Page
Table 2-1 Long-Term Monitoring Tag List 2-4
Table 2-2 Instrument and Analysis Accuracy Specifications 2-4
Table 3-1 Recommended Calibrations and Performance Checks 3-2
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ACRONYMS AND ABBREVIATIONS
A ampere
Btu/h British thermal units per hour
Btu/scf British thermal units per
standard cubic foot
CHP combined heat and power
CO2 carbon dioxide
CO carbon monoxide
CT current transformer
DG distributed generation
DG / CHP distributed generation /
combined heat and power
DQO data quality objective
EPA Environmental Protection
Agency
ETV Environmental Technology
Verification
gpm gallons per minute
HRLHV heat rate, LHV basis, Btu/kWh
Hz Hertz
kW kilowatt
KVA kilovolt-ampere
KVAR kilovolt-ampere reactive
Ib/h pounds per hour
Ib/kWh pounds per kilowatt-hour
LHV lower heating value
MQO measurement quality objective
MTG microturbine
NOX nitrogen oxides
NYSERDA New York State Energy
Research and Development
Authority
O2 oxygen
ppmv volume parts per million
QA / QC quality assurance / quality
control
RTD resistance temperature device
SCADA supervisory control and data
acquisition
THC total hydrocarbons
THD total harmonic distortion
Tr return temperature
Ts supply temperature
degrees Fahrenheit
efficiency, percent
DISTRIBUTION LIST
New York State Energy Research and Development Authority
Jim Foster
Mark Gundrum
OfficePower LLC
Robert Jannino
John Pifer
U.S. EPA Office of Research and Development
Blair Martin
Robert Wright
Southern Research Institute (GHG Center)
Tim Hansen
William Chatterton
Eric Ringler
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Final April, 2008
1.0 INTRODUCTION
The intent of this Test and Quality Assurance Plan (test plan) is to guide the planning, execution, data
analysis, and reporting for performance verification of an Elliott Microturbine (MTG) distributed
electrical generation and combined heat and power (DG / CHP) installation owned and operated by
OfficePower, Inc.
OfficePower has installed eight natural gas-fired Model TA 100 kilowatt, (kW) machines into two arrays
of four MTG each in a 39-story office building located at 110 East 59th Street in New York City, NY.
Appendix B provides MTG specifications while Figure 2-2 shows an overall layout schematic.
The MTG arrays operate in response to building electrical demand; power is not exported to the grid. The
installation recovers substantial amounts of thermal energy from the MTG exhaust which the building
uses for space heating and cooling. Design specifications indicate that the recovered energy will displace
up to 4.7 million British thermal units per hour of the high pressure steam purchased from the local
utility. Parasitic loads include booster compressors to raise the as-delivered natural gas pressure to
approximately five pounds per square inch, heat transfer fluid circulation pumps, and a separate fan-
cooled radiator for emergency use during upsets. The as-built system collects all parasitic loads into a
single cabinet for control and quantification by a revenue-quality power meter. Revenue-quality meters
also measure power and thermal energy production, providing 5-minute data points for system operations
use and 15-minute averages for billing purposes.
The test campaign will determine the emissions performance, electrical performance, and electrical
efficiency of MTG unit number 6 during a "controlled test period". A two-week "long-term monitoring
period" will quantify the power production, recovered CHP thermal energy (heat) production, electrical
efficiency, thermal efficiency, and total efficiency of the as-dispatched system.
1.1. PURPOSE
The New York State Energy Research and Development Authority (NYSERDA) and the U.S.
Environmental Protection Agency (EPA) Environmental Technology Verification (ETV) program have
commissioned this test campaign. Test results also are of interest to the ETV program because previous
verifications have not included either the Elliott MTG or multi-microturbine arrays.
1.2. PARTICIPANTS, ROLES, AND RESPONSIBILITIES
Southern Research Institute (Southern) will manage the test campaign. Responsibilities include:
• test strategy development and documentation
• coordination and execution of all field testing, including:
o installation, operation, and removal of emissions testing equipment
o providing electrical power monitoring and datalogging equipment
o subcontract management for installation and removal of electrical power monitors
• inspection of calibrations, performance of crosschecks, and other activities to verify
the host facility's as-built sensors and monitoring equipment performance
• data validation, quality assurance and quality control (QA / QC), and reporting
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OfficePower's installation at 110 East 59th Street in New York City will serve as the host facility.
Southern will work closely with OfficePower personnel to ensure reasonable access to the host facility
and minimal effects on the facility's normal operations.
Figure 1-1 lists test participants and their titles.
Robert Wright
US EPA APPCD
QA Manager
Blair Martin
ITS FPA APPPn
Project Officer
Tim Hansen
GHG Center Director
Eric Ringler
GHG Center
QA Manager
Bill Chatterton
GHG Center
Project Manager
John Pifer
OfficePower
Engineering Manager
Bob Richards
GHG Center
Field Team Leader
Burl McEndree
Empact Analytical
Fuel Gas Analyses
Figure 1-1. Test Participants
Tim Hansen is the GHG Center Director. He will:
• ensure the resources are available to complete this verification
• review the test plan and verification report to ensure they conform to ETV principles
• oversee GHG Center staff and provide management support where needed
• sign the verification statement, along with the EPA-ORD laboratory director.
Bill Chatterton will serve as the Project Manager for the GHG Center. He will have authority to suspend
testing in response to health or safety issues or if data quality indicator goals are not met. His
responsibilities also include:
• drafting the test plan and verification report
• overseeing the field team leader's data collection activities
• ensuring that data quality objectives (DQO) are met prior to completion of testing
• maintaining effective communications between all test participants
Bob Richards will serve as the Field Team Leader. He will:
• provide field support for activities related to all measurements and data collected
• install and operate the measurement instruments
• collect gas samples and coordinate sample analysis with the laboratory
• ensure that QA / QC procedures outlined in this test plan are followed
• submit all results to the Project Manager to facilitate his determination that DQOs are
met
Southern's GHG Center QA Manager, Eric Ringler, is administratively independent from the GHG
Center Director and the field testing staff. Mr. Ringler will:
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• ensure that all verification tests are performed in compliance with the QA
requirements of the GHG Center quality management plan, the generic protocol [1],
and this test plan
• review the verification test results and ensure that applicable internal assessments are
conducted as described in the test plan
• reconcile the DQOs at the conclusion of testing
• conduct or supervise an audit of data quality
• review and validate subcontractor-generated data
• report all internal reviews, DQO reconciliation, the audit of data quality, and any
corrective action results directly to the GHG Center Director, who will provide
copies to the project manager for corrective action as applicable and citation in the
final verification report
• review and approve the final verification report and statement
Fuel gas analyses will be conducted by Empact Analytical of Brighton, Colorado under the management
of Burl McEndree.
EPA-ORD will provide oversight and QA support for this verification. The APPCD Project Officer, Blair
Martin, is responsible for obtaining final approval of the Test Plan and Report. The APPCD QA Manager
will review this test plan and the final Report to ensure they meet the GHG Center Quality Management
Plan requirements and represent sound scientific practices.
OfficePower will collect data during the long term monitoring period from the as-built host facility
sensors and equipment. John Pifer of OfficePower will coordinate transfer of these data files.
1.3. TEST SCHEDULE
The host facility's electrical design normally requires that all eight MTG be in service to meet the
expected demand. The design demand occurs during regular office hours. The automated control system
normally shuts down most or all of the MTG on nights or weekends because of reduced thermal demand.
The controlled test runs will occur on unit 6 only. This means that the other 7 MTG must be shut down
and not dispatched during the controlled test period. Normal dispatching will resume as soon as this test
period is finished. Also, Southern will install MTG and parasitic load electric power monitoring
equipment for use during the controlled test period. This will require de-energizing the electrical feed
briefly during installation and removal.
Figure 1-2 shows the intended test schedule. OfficePower and Southern will specify the test dates upon
completion of the installation and commissioning process.
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April, 2008
Day 1
Test Schedule
Day 2
Day3
Arrive at site
Conduct orientation, safety, and other
conferences
Unpack Southern's test equipment,
mobilize, and perform preliminary setups
Install exhaust duct test ports
Install PEMS and accessory emissions test
equipment
Warmup PEMS and perform preliminary
calibrations
Prepare unit 6 and parasitic load electric
power monitors for installation
Install Ts, Tr cross-check sensors in building
water line "Pete's plugs."
Conduct Ts, Tr cross-checks during normal
operations
De-energize unit 6 control and parasitic load
cabinets
Connect electric power monitors (use
contract electrician, if required)
Re-energize unit 6 and resume normal
operations
Perform all remaining cross-checks and
review all site sensor calibrations
Configure SCADA and verify data collection
capability for controlled test and long-term
monitoring periods
Day 4
Day5
Withdraw both MTG arrays from normal
dispatching and shut them down
Start unit 6 and load it at 100 % of capacity
Perform 3 controlled test runs, 1 hour each
on unit 6
Collect natural gas samples, if required
Verify data collection, permissible
variations, pre- and post-test PEMS
calibrations, etc.
Remove unit 6 and parasitic load electric
power monitors
Restore normal dispatching
Begin 2-week long term monitoring period
Remove and de mobilize all Southern's
test equipment
Pack for shipping and closeout
Figure 1-2. Test Schedule
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Final April, 2008
2.0 TEST PROCEDURES
The ETV program has published the Distributed Generation and Combined Heat and Power Field Testing
Protocol [1] (generic protocol). The generic protocol contains detailed test procedures, instrument
specifications, analytical methods, and QA / QC procedures. This test campaign will generally conform
to the generic protocol specifications, with modifications or special considerations as listed in the
following subsections. Appendix A provides field data forms as derived from the generic protocol.
2.1. TEST CONCEPTS AND OBJECTIVES
The test campaign will proceed in two phases:
• controlled test period
• two-week long-term monitoring period
2.1.1. Controlled Test Period
Southern test personnel will be on-site during the controlled test period to perform the following
determinations on MTG unit 6:
• electrical performance (see generic protocol §2.0 for parameters and specifications;
Appendix Dl for definitions and equations)
• electrical efficiency (see generic protocol §3.0 for parameters and specifications;
Appendix D2 for definitions and equations)
• gaseous carbon monoxide (CO), carbon dioxide (CO2), nitrogen oxides (NOX) and
total hydrocarbons (THC) emissions performance (see generic protocol §5.0)
The controlled test period will consist of three (3) test runs, each one (1) hour long, while unit 6 operates
at 100 percent capacity. The generic protocol also recommends testing at 25, 50, and 75 percent capacity,
but the host facility is not designed for that capability.
Southern will coordinate the installation of independent electrical power analyzers on the unit 6 output
bus and at the central parasitic load control cabinet. Parasitic loads include:
• glycol loop circulation pump
• cooling radiator fan
• booster compressors
• chiller loads (not yet installed)
The loads are likely to consume up to approximately 10 percent of the full array's power output. Figure 1
shows the instrument locations. The analyzers will record the electrical performance parameters at 1-
minute intervals or shorter.
Southern will determine gaseous emissions as CO, CO2, NOX, and THC concentrations with a Horiba
OBS-2200 portable emissions monitoring system. Test personnel will temporarily install the PEMS and
two volumetric flow test ports on the unit 6 exhaust stack. They will conduct one Title 40 CFR 60
Appendix A, Method 2 volumetric flow traverse during each test run while the PEMS gathers emissions
concentrations. The mean concentration for each gas, integrated with the mean volumetric flow rate will
yield the gaseous emission rate in pounds per hour. Note that facility operators will set the unit 6 bypass
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April, 2008
damper to the bypass position during the controlled test period. CHP heat recovery data will be collected
during long-term monitoring only.
Southern will log natural gas consumption data directly from the two utility revenue meters located in the
building basement. Test personnel will collect natural gas samples for lower heating value (LHV)
analysis.
A Ts~l Velocity /volume trav
/*"^S Vs_J~ during controlled test
CO.C02, "I fflissio
_/~\ NOX.THC. U Ho"*C
— {J HSO.PambJ P™
— ' monitori
. CHP heat exch
Microturbine
llnitttfi _..
*•
ij
Electrical performance;
ION 7600 power
meter and datalogger \
kW, kVAR,\
PF, V, A, r~\
Hz.THD V_J
1 >^^
. |s,>|
<* T
,^2i jv,-*i
_ W
I
*^\ **™*1l
erses
period
ns performance;
)BS-2200
emissions
ng system (PEMS)
Heat transfer fluid lines
anger to /from building heat
exchanger
•> - '
IY
8^
b J" 1
Vfuel, scfm^
"-Ct?-
T^^-
kW, kVAR,
PF.V.A
Hz.THD ( }
^N.
-,
. 1 \
A\
Thermostatically-controlled
heat dump radiator
Electrical efficiency: fuel
^^consumption; utility fuel meter
(meter odometer manual readings)
Fuel compressor
NOTE:
Bypass damper set to bypass mode
during controlled test period only
LA_A_A_J Parasitic loads; ION
r^On 7500 power meter Building water or
1 1 and datalogger heat transfer fluid lines
Natural gas lines
Figure 2-1. Controlled Test Instrument Locations
2.1.2. Long-term Monitoring Period
The long-term monitoring period will provide assessments of the following for the two banks of four
MTG each:
• electric power production, net
• electrical efficiency
• CHP thermal performance (see generic protocol §4.0 for parameters and
specifications, Appendix D3 for definitions and equations)
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April, 2008
• CHP and total efficiency (see generic protocol Appendix D3 for definitions and
equations)
The host facility has installed a well-designed suite of revenue service-capable power and thermal energy
monitors with their associated sensors, signal conditioners, dataloggers, and support equipment. These
meet the generic protocol accuracy and precision specifications for the electrical and heat recovery
parameters of interest. The host facility supervisory control and data acquisition (SCADA) system is
capable of recording the required parameters in MicroSoft Excel worksheet format with timestamps.
NIST-traceable calibration certificates, manufacturer specifications, and independent cross checks to be
performed by Southern (see §3.5) will support the use of data from these instruments. Figure 2 provides
an instrument location schematic.
MTG heat transfer loop
to building water loop
heat exchanger
Thermostatically-
controlled heat dump
radiator
Building hot
water supply line
Building steam heat
exchanger; steam
purchased from
Consolidated Edison
Building cold
water return line
Bank 2
kW, kVAR
PF, V, A,
Hz, THD
Fuel booster
compressor
NOTE:
OfficePower SCADA system
to log all parameters at
30-second intervals throughout
long-term monitoring period.
Electrical lines
Building water or
heat transfer fluid lines
Natural gas lines
Figure 2-2. Long-Term Monitoring Instrument Locations
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The electrical, thermal, and total efficiency determinations require fuel LHV data. Analysts will use the
mean laboratory LHV results from the samples collected during the controlled test period for the
efficiency calculation.
OfficePower representatives will configure the SCADA system to record the long-term monitoring data at
five-minute intervals during normal daily operations. Table 2-1 provides a tag list and descriptions
Table 2-1. Long-Term Monitoring Tag List
Item
1
2
3
4
5
6
7
8
Description
Timestamp
MTG array # 1 energy production
MTG array #2 energy production
Building heat exchanger water flow rate
Building water supply temperature
Building water return temperature
Natural gas consumption, meter 1
Natural gas consumption, meter 2
Units
mm/dd/yyyy hh:mm:ss
kWh
kWh
gpm
°F
°F
scf
scf
Tag ID
n/a
WTA1
WTA2
FGL
TGLS
TGLR
FGM1
FGM2
2.1.3. Instrument Specifications
The generic protocol provides detailed specifications for all instruments or analyses. Table 2-2 provides a
synopsis.
Table 2-2. Instrument and Analysis Accuracy Specifications"
Parameter
Voltage
Current
Real Power
Reactive power
Frequency
Power Factor
Voltage THD
Current THD
CT
CT
Temperature
Barometric pressure
Gas flow
LHV analysis by ASTM D 1945 [8]
and D3588 [9]
Heat transfer fluid flow
Tsuppiy, Tretum temperature sensors
Gaseous emissions concentrations
Method 2 volumetric flow rate
Accuracy
+ 0.5 %
+ 0.4 %
+ 0.6 %
+ 1.5 %
+ 0.01 Hz
+ 2.0 %
+ 5.0 %
+ 4.9 % to 360 Hz
+ 0.3 % at 60 Hz
+ 1.0% at 360 Hz
±1 °F
±0.1 in. Hg (±0.05psia)
+ 1.0%6
+ 1.0 %
+ 1.0 %
+ 0.6°F
+ 2.0% of span"
+ 5.0 %
"All accuracy specifications are percent of reading unless otherwise noted.
^Utility gas meter is temperature- and pressure-compensated.
'PEMS conforms to or exceeds Table 1 of Title 40 CFR 1065.915
specifications.
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April, 2008
2.2. SITE-SPECIFIC CONSIDERATIONS
Section 6.0 of the generic protocol lists step-by-step procedures for the controlled test period. This
subsection considers site-specific testing, safety, or other actions which the field team will implement.
Appendix A of this test plan provides the necessary field data forms.
Emissions testing
Unit 6 has a 1A" NPT male test port at the base of its exhaust stack.
PEMS test probe at this port.
Southern will temporarily install the
The vertical exhaust ducts have a 10" inner flue, 14" outer sheath, and 2" thick insulation. The
volumetric flow traverses will require two 1A" diameter test ports at the locations shown in Figure 2-3 .
Test personnel will first temporarily secure a plank laid along the structural steel for staging. They will
then remove the retaining clamp for access to the inner flue. The two !/2" diameter holes for the test ports
must be at 90° around the circumference of the flue from each other. When tests are finished, test
personnel will install a 10" diameter sheet metal clamp around the flue, sealing it with high-temperature
gasket material. They will then re-install the retention clamp and remove the staging.
The staging will be approximately 12' above the floor level. Southern test personnel will wear safety
harnesses and tethers secured to the structure while working at elevated heights.
Retaining clamp.
Test ports to be
located under
the clamp.
Figure 2-3. Volumetric Flow Testing Location
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Final April, 2008
Electrical power monitors
Southern will coordinate the temporary installation of the unit 6 and parasitic load electric power
monitors by a qualified electrician. The generic protocol, Figure F-l of Appendix F2, provides a wiring
schematic. Southern will provide the power monitors, shorting switches, current transmitters (CT), and
miscellaneous supplies. These tests will employ split-core CTs which can be installed without disturbing
the MTG bus conductors. The power meters will, however, require direct voltage connection to each
phase. The MTG and parasitic load electrical feed must be shut down briefly during the connection
procedure and while installing the CTs.
Natural gas sampling
Southern will collect at least three natural gas samples during the controlled test period and three
additional samples at the end of the long-term monitoring period. The sampling location is on the MTG
side of the fuel gas booster. Expected pressure is five pounds per square inch, gauge. Test personnel will
connect an evacuated sample bottle to the sample port and purge it for at least 30 seconds prior to capping
and sealing during each sampling event. Analysts will compare the mean LFfV between the two sets of
samples to evaluate potential changes in the gas supply. They will also use the mean LFfV in the
electrical and CHP efficiency determinations. Appendices A6 and A7 provide a sampling log and chain
of custody form, respectively
Building water system supply and return temperature crosschecks
Section 3.1 describes the building supply and return temperature crosschecks. The supply and return
pipelines incorporate the CHP heat recovery temperature sensors (see Figure 2-2). The building water
piping includes 1/8" diameter "Pete's Plugs" adjacent to the as-built supply temperature (Ts) and return
temperature (Tr) sensors. These self-sealing fittings allow insertion of check thermometers and other
devices while the system remains under pressure. Test personnel will install 1/8" diameter platinum
resistance temperature device (RTD) probes in these locations for the crosschecks.
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Final April, 2008
3.0 DATA QUALITY
Southern operates the Greenhouse Gas Technology Center (GHG Center) for the U.S. Environmental
Protection Agency's Environmental Technology Verification program. Southern's analysis and QA / QC
procedures generally conform to the Quality Management Plan, Version 1.4, developed for the GHG
Center.
3.1. DATA ACQUISITION
Test personnel will collect the following electronic data files:
controlled test power output and power quality parameters (power meter number 1)
controlled test parasitic loads (power meter number 2)
controlled test emissions concentrations (PEMS)
heat transfer fluid temperature crosschecks (datalogger)
long-term monitoring period power output, parasitic loads, and fuel consumption
(SCADA)
The two controlled test power meters will poll their sensors once per second. They will then calculate
and record one-minute averages. The field team leader will download the one-minute data directly to a
laptop computer during the short-term tests. The SCADA system will record each parameter at 5-minute
intervals during the controlled test and long-term monitoring periods.
Test personnel will record printed or written documentation on the log forms provided in Appendix A,
including:
• daily test log, including test run starting and ending times, notes, etc.
• appendix A forms which show the results of QA / QC checks
• copies of calibrations and manufacturers' certificates
The GHG Center will archive all electronic data, paper files, analyses, and reports at their Research
Triangle Park, NC office in accordance with their quality management plan.
3.2. DATA REVIEW, VALIDATION, AND VERIFICATION
The project manager will initiate the data review, validation, and analysis process. Analysts will employ
the QA / QC criteria specified in §3.5 to classify all collected data as valid, suspect, or invalid.
In general, valid data results from measurements which:
• meet the specified QA / QC checks
• were collected when an instrument was verified as being properly calibrated
• are consistent with reasonable expectations, manufacturers' specifications, and
professional judgment
The report will incorporate all valid data. Analysts may or may not consider suspect data, or it may
receive special treatment as will be specifically indicated. If the DQO cannot be met, the project manager
will decide to continue the test, collect additional data, or terminate the test and report the data obtained.
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Final April, 2008
Data review and validation will primarily occur at the following stages:
• on site ~ by the field team leader,
• upon receiving subcontractor or laboratory deliverables,
• before writing the draft report ~ by the project manager, and
• during draft report QA review and audits ~ by the GHG Center QA Manager.
3.3. INSPECTION AND ACCEPTANCE OF SUPPLIES, CONSUMABLES, AND SERVICES
Procurement documents shall contain information clearly describing the item or service needed and the
associated technical and quality requirements. Consumables for this verification will primarily consist of
NIST-traceable calibration gases. Fuel analysis will be the only purchased service. The procurement
documents will specify the QA / QC requirements for which the supplier is responsible and how
conformance to those requirements will be verified.
Procurement documents shall be reviewed for accuracy and completeness by the project manager and QA
manager. Appropriate measures will be established to ensure that the procured items and services satisfy
all stated requirements and specifications.
3.4. DATA QUALITY OBJECTIVES
The generic protocol [1] provides the basis for the DQOs to be achieved in this verification. Previous DG
/ CHP verifications and peer-reviewed input from EPA and other stakeholders contributed to the
development of those specifications. Tests which meet the following quantitative DQOs will provide an
acceptable level of data quality to meet the needs of technology users and decision-makers.
Verification Parameter DQO (relative uncertainty)
electrical performance as generated power ± 2.0 %
electrical efficiency ± 2.5 %
CHP thermal efficiency ±3.5%
Each test measurement that contributes to a verification parameter has stated measurement quality
objectives (MQO) which, if met, ensure achievement of that parameter's DQO. Table 2-2 summarizes
the generic protocol MQOs as accuracy specifications for each instrument or measurement.
The gaseous emissions DQO is qualitative in that this verification will produce emission rate data that
satisfies the QA / QC requirements for EPA reference methods. The verification report will provide
sufficient documentation of the QA / QC checks to evaluate whether the qualitative DQO was met.
The completeness goal for this verification is to obtain valid data for 90 percent of each controlled test
period.
A fundamental component of all verifications is the reconciliation of the collected data with its DQO.
The DQO reconciliation will consist of evaluation of whether the stated methods were followed, MQOs
achieved, and overall accuracy is as specified in the generic protocol and this test plan. The field team
leader and project manager will initially review the collected data to ensure that they are valid and are
consistent with expectations. They will assess the data's accuracy and completeness as they relate to the
stated QA / QC goals. If this review of the test data show that QA / QC goals were not met, then
immediate corrective action may be feasible, and will be considered by the project manager. DQOs will
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April, 2008
be reconciled after completion of corrective actions. As part of the internal audit of data quality, the GHG
Center QA Manager will include an assessment of DQO attainment.
3.5. CALIBRATIONS AND PERFORMANCE CHECKS
Sections 7.1 through 7.3 of the generic protocol specify a variety of technical system audits and QA / QC
checks for the electrical performance, electrical efficiency, and CHP performance determinations. This
test campaign will perform those that are applicable to the host facility. The final test report will cite the
results for each QA / QC check.
In addition to the CHP data validation procedures cited in §7.3 of the generic protocol, Southern will
conduct a cross-check of the building water supply and return temperature sensors. Test personnel will
insert calibrated RTDs into the pipeline adjacent to the as-built sensors through self-sealing fittings. They
will record steady-state temperature data from the SCADA display and RTDs at least once per minute for
at least ten minutes while the MTG array is idle. The temperatures during normal, steady-state operations
will also be recorded while the system is delivering CHP energy to the building. The mean steady-state
temperatures should agree within ± 0.98 °F for each as-built temperature sensor and the adjacent RTD.
The electrical power monitoring equipment installed for the controlled test period will serve as a cross-
check for the SCADA power instruments. Analysts will compare the electrical performance data logged
from the two sources for each test run. Mean values, in general, should agree within approximately ± 2
percent for generated power and ± 7 percent for total harmonic distortion. If possible, OfficePower will
dispatch the entire MTG array for at least 1A hour to enable comparisons at full power output.
The generic protocol specifies Title 40 CFR 60 Appendix A source test methods to determine gaseous
pollutant emissions. This test campaign, however, will employ a Horiba OBS-2200 PEMS that meets
Title 40 CFR 1065 [2] specifications. Southern will also deploy a Testo 350 multi-gas combustion
analyzer as a backup instrument. Test personnel will conduct the technical system audits, calibrations,
performance checks, and cross checks listed in Table 3-1.
Table 3-1. Recommended Calibrations and Performance Checks
System or Parameter
Pressure transducers
Temperature
transducers (Tmtake,
Texh)
All instrumental
analyzers
CO2 (NDIR detectors)6
CO (NDIR detectors)
Hydrocarbon analyzer
(FID)C
NOX analyzer
NOX analyzer
Description / Procedure
NIST-traceable" calibration
1 1 -point linearity check
H2O interference
CO2, H2O interference
Propane (C3H8) calibration
FID response optimization
C3H8 / methyl radical (CH3)
response factor determination
C3H8 / CH3 response factor check
Oxygen (O2) interference check
CO2 and H2O quench (CLD)"
Non-methane hydrocarbons
(NMHC) and H2O interference
(NDUV detectors)"
Ammonia interference and NO2
Frequency
Within 12 months
Within 12 months
Within 12 months
Within 12 months
Meets
Spec.?
n
n
n
D
rj
D
n
n
n
Date
Completed
response (zirconium dioxide
3-3
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Final
April, 2008
Table 3-1. Recommended Calibrations and Performance Checks
System or Parameter
Complete PEMS
Testo (if used)
Exhaust gas or intake
air flow measurement
device
Description / Procedure
detectors)
Chiller NO2 penetration (PEMS
with chillers for sample moisture
removal)
NO2 to NO converter efficiency
Comparison against laboratory CVS
system
Zero / span analyzers (zero < + 2.0
% of span, span < + 4.0 % of point)
Perform analyzer drift check (< +
4.0 % of cal gas point)
NMHC contamination check (< 2.0
% of expected cone, or < 2 ppmv)
100 ppm CO cal gas crosscheck
with Testo
Zero / span analyzers (zero < + 2.0
% of span, span < + 4.0 % of point)
Perform analyzer drift check (< +
4.0 % of cal gas point)
100 ppm CO cal gas crosscheck
with PEMS
Differential pressure line leak check
(AP stable for 1 5 seconds at 3
"H2O)
Frequency
Within 6 months or immediately
prior to departure for field tests
At purchase / installation; after
major modifications
Before and after each test run
After each test run
Once per test day
At least once per test day
Before and after each test run
After each test run
At least once per test day
Once per test day
Meets
Spec.?
n
D
D
Refer to
Appendix
A2, "Test
Run
Record"
D
D
D
n
Date
Completed
"National Institutes of Standards and Technology (MIST)
*non-dispersive infrared (NDIR)
cflame ionization detector (FID)
dchemilumenescence detector (CLD)
"non-dispersive ultra violet (NDUV)
3.6. AUDITS OF DATA QUALITY
The reported results will include many contributing measurements from numerous sources. Data
processing will require different algorithms, formulae, and other procedures. Original datalogger ASCII
text files, the host facility's SCADA system Excel-format file outputs, signed logbook entries, and signed
field data forms will be the source for all Excel worksheets used as analysis tools. The GHG Center QA
manager will:
• manually calculate each reported result based on ten percent of the raw data files,
including the applicable engineering conversions
• compare the manually-calculated result with the worksheet file and the draft report
• in the event that errors are found, manually calculate a higher proportion of each
reported result and resolve any problems.
3.7. INDEPENDENT REVIEW
The GHG Center QA manager will examine this test plan, the report text, and all test results. The analyst
or author who produces a result table or text will submit it (and the associated raw data files) to him or to
an independent technical or editorial reviewer. Reviewers will be Southern employees with different
lines of management supervision and responsibility from those directly involved with test activities.
3-4
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Final April, 2008
4.0 ANALYSIS AND REPORTS
The test report will summarize field activities and present results. Attachments will include sufficient raw
data to support the findings and allow reviewers to assess data trends, completeness, and quality. The
report will clearly characterize the test parameters, their results, and supporting measurements as
determined during the test campaign. It will present raw data and analyses as tables, charts, or text as is
best suited to the data type.
The report will group the results separately for the controlled test runs and long-term monitoring period.
The long term monitoring period results will likely fall into three subgroups:
• both MTG arrays operating with eight units
• one MTG array operating with four units
• overall mean results including downtime
Reported results will include:
• run-specific mean, maximum, minimum, and standard deviation
• run-specific assessment of the permissible variations within the run for the controlled
test period
• overall mean, maximum, minimum, and standard deviation for all valid test runs
• ambient conditions (temperature, barometric pressure) observed during each
controlled test run and a comparison between the observed conditions and the
standard conditions at which the manufacturer rated the DG (usually ISO standard of
60 °F, 14.696 psia)
• description of measurement instruments and a comparison of their accuracies with
those specified in the generic protocol
• summary of data quality procedures, results of QA/QC checks, the achieved accuracy
for each parameter, and the method for citing or calculating achieved accuracy
• copies of laboratory QA documentation, including calibration data sheets, duplicate
analysis results, etc.
• results of data validation procedures including a summary of invalid data and the
reasons for its invalidation
• information regarding any variations from the procedures specified in this test plan
• narrative description of the DG installation, site operations, and field test activities
including observations of site details that may impact performance. These include
thermal insulation presence, quality, mounting methods that may cause parasitic
thermal loads etc.
The following subsections itemize the reported parameters. Appendix D of the generic protocol provides
the relevant definitions and equations.
4.1. ELECTRICAL PERFORMANCE
The electrical performance test reports will include:
• total real power without external parasitic loads, kW
• total reactive power, kilo-volt-ampere reactive (kVAR)
total power factor, percent
4-1
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Final April, 2008
• voltage (for each phase and average of all three phases), volts (V)
• current (for each phase and average of all three phases), amperes (A)
• frequency, Hertz (Hz)
• Voltage total harmonic distortion (THD) (for each phase and average of all three
phases), percent
• Current THD (for each phase and average of all three phases), percent
• apparent power consumption for the external parasitic loads, kilo-volt-amperes
(kVA)
• total real power including debits from all external parasitic loads, kW
4.2. ELECTRICAL EFFICIENCY
Electrical efficiency test reports will include:
• electrical generation efficiency (TI^LHY) without external parasitic loads
• electrical generation efficiency (TI^LHY) including external parasitic loads
• heat rate (HRLHv) without external parasitic loads
• heat rate (HRLHv) including external parasitic loads
• total kW
• heat input, British thermal units per hour (Btu/h) at a given electrical power output
• fuel input, standard cubic feet per hour (scfh)
The report will quote all laboratory analyses for the fuel LHV in British thermal units per standard cubic
foot (Btu/scf).
Note that electrical generation efficiency uncertainty should be reported in absolute terms. For example,
if T|e,LHv for gaseous fuel is 26.0 percent and all measurements meet the accuracy specifications, the
relative error is ± 3.0 percent (see generic protocol Table 7-4). The absolute error is 26.0 times 0.030, or
± 0.78 percent. The report, then, should state rjeLHv as "26.0 ± 0.8 percent". This will prevent confusion
because, for efficiency, both relative and absolute errors can be reported as percentages.
4.3. CHP THERMAL PERFORMANCE
The thermal performance report for the CHP system in heating service will include:
• actual thermal performance (Qout), Btu/h
• actual thermal efficiency (TJ^LHY)
• actual total system efficiency (r|tot LHv)
• heat transfer fluid supply and return temperatures, degrees Fahrenheit (°F), and flow
rates, gallons per minute (gpm) for each heat transfer fluid loop measured
The report will cite r|th and r|tot and their achieved accuracies in absolute terms because efficiency and
relative accuracies are both percentages. Refer to the previous subsection for a discussion on avoiding
potential confusion due to terminology.
4-2
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Final April, 2008
4.4. ATMOSPHERIC EMISSIONS
Reported parameters for each test run will include the following:
• emission concentrations for carbon monoxide (CO), nitrogen oxides (NOX), and total
hydrocarbons (THC) evaluated in volume parts per million (ppmv) corrected to 15
percent O2
• emission concentration for carbon dioxide (CO2) corrected to 15 percent O2
o Note: the correction equation is:
20.9-15
Where:
ccorr = concentration corrected to 15 percent O2, ppmv or percent
Q = mean concentration of the constituent i, ppmv or percent
20.9 = atmospheric O2 content, percent
O2 = mean exhaust gas O2 content, percent
• emission rates for CO, CO2, NOX, and THC evaluated as Ib/hr and Ib/kWh electrical
generation
• exhaust gas dry standard flow rate, actual flow rate, and temperature
• exhaust gas composition, moisture content, and molecular weight
4-3
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Final April, 2008
[blank page]
4-4
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Final April, 2008
5.0 REFERENCES
[1] Generic Verification Protocol — Distributed Generation and Combined Heat and Power Field
Testing Protocol, Version 1.0, SRI/USEPA-GHG-GVP-04, Southern Research Institute and US EPA
Environmental Technology Verification (ETV) Program, available at:
, Washington, DC 2005
[2] Engine-Testing Procedures, Title 40 CFR 1065, Environmental Protection Agency, Washington,
DC, adopted at 70 FR 40410, 13 July, 2005
5-1
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Final
April, 2008
[Blank Page]
5-2
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Final April, 2008
Appendix A
Field Data Forms
-------
Final
April, 2008
Appendix Al: Distributed Generator Installation Data
Project Name: OfficePower
Compiled by: (Company)
Date:
Signature:
Address 1:
Address 2:
Site Information
Owner Company:
Contact Person:
City, State, Zip:
Op'r or Technician:
Site Phone:
Address (if different):
Company Phone:
Fax:
Modem Phone (if used):
Altitude 247 (feet)
Utility Name: Consolidated Edison
Contact Person:
Utility Phone:
Installation (check one): Indoor Outdoor Utility Enclosure Other (describe)
Sketch of HVAC systems attached (if Indoor) Controls: Continuous Thermostatic
Other
Primary Configuration, Service Mode, and CHP Application
(check all that apply; indicate secondary power and CHP application information with
an asterisk, * )
Delta
Single Phase
Inverter
Grid Parallel
Demand
Management
Hot water
Indirect chiller
Wye
Three Phase
Induction
Grid Independent
Prime Power
Backup Power
Steam
Grounded Wye
Synchronous
Peak Shaving
Load Following
VAR Support
Direct-fired chiller
Other DG or CHP (describe)
Date:
Generator Nameplate Data
_Local Time (24-hour): Hour meter:
Commissioning Date:
Manufacturer:
Model:
Site Description
(Check one)
Hospital
University
Resident' 1
Industrial
Utility
Hotel
Other (desc.)
Office
building
Fuel
(Check one)
Nat'l Gas X
Biogas
Landfill G
Diesel #2
Other (desc.)
Serial #:
Prime mover (check one): 1C generator MTG
Range: to (kW; kVA) Adjustable? (y/n) Power Factor Range: to Adjustable? (y/n)
Nameplate Voltage (phase/phase):
Amperes: Frequency:
Hz
Controller (check one): factory integrated 3rd-party installed custom (describe)_
A-l
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Final
April, 2008
Appendix Al: Distributed Generator Installation Data (cont.)
CHP Nameplate Data
BoP Heat Transfer Fluid Loop
Describe:
Nominal Capacity:
(Btu/h) Supply Temp.
(°F) Return Temp.
Low Grade Heat loop
Describe:
Nominal Capacity:
Chilling loop
Describe:
Nominal Capacity:
(Btu/h) Supply Temp.
(Btu/h) Supply Temp.
(°F) Return Temp. (°F)
(°F) Return Temp. (°F)
Other loop(s): Describe:
Nominal Capacity:
(Btu/h) Supply Temp.
(°F) Return Temp.
Parasitic Loads
Enter nameplate horsepower and estimated power consumption. Check whether internal or external. Internal
parasitic loads are on the DG-side of the power meter. External parasitic loads are connected outside the system
such that the power meter does not measure their effects on net DG power generation.
Description
Fuel Gas Compressor
CHP Heat Transfer Fluid Pump - Hot Fluid
CHP Heat Transfer Fluid Pump - Low Grade
CHP Heat Transfer Fluid Pump - Chilling
Fans (describe)
Name-
plate Hp
Est. kVA
orkW
Internal
(")
External
(")
Function"
Other: Transformers, etc. (describe)
"Describe the equipment function. Also note whether the equipment serves multiple units or is dedicated to the test DG.
A-2
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Final April, 2008
Appendix A2. Power Meter Commissioning Procedure
1. Obtain and read the power meter installation and setup manual. It is the source of the items
outlined below and is the reference for detailed information.
2. Verify that the power meter calibration certificate, CT manufacturer's accuracy certification,
supplementary instrument calibration certificates, and supporting data are on hand.
3. Mount the power meter in a we 11-ventilated location free of moisture, oil, dust, corrosive vapors,
and excessive temperatures.
4. Mount the ambient temperature sensor near to but outside the direct air flow to the DG
combustion air inlet plenum but in a location that is representative of the inlet air. Shield it from
solar and ambient radiation.
5. Mount the ambient pressure sensor near the DG but outside any forced air flows. Note: This test
will use the Horiba OBS-2200 ambient pressure sensor.
6. Ensure that the fuel consumption metering scheme is in place and functioning properly.
7. Verify that the power meter supply source is appropriate for the meter (usually 110 VAC) with
the DVM and is protected by a switch or circuit breaker.
8. Connect the ground terminal (usually the "Vref" terminal) directly to the switchgear earth ground
with a dedicated AWG 12 gauge wire or larger. Refer to the manual for specific instructions.
9. Choose the proper CTs for the application. Install them on the phase conductors and connect them
to the power meter through a shorting switch to the proper meter terminals. Be sure to properly
tighten the phase conductor or busbar fittings after installing solid-core CTs.
10. Install the voltage sensing leads to each phase in turn. Connect them to the power meter terminals
through individual fuses.
11. Trace or color code each CT and voltage circuit to ensure that they go to the proper meter
terminals. Each CT must match its corresponding voltage lead. For example, connect the CT for
phase A to meter terminals IAi and IA2 and connect the voltage lead for phase A to meter terminal
VA.
12. Energize the power meter and the DG power circuits in turn. Observe the power meter display (if
present), datalogger output, and personal computer (PC) display while energizing the DG power
circuits.
13. Perform the power meter sensor function checks. Use the DVM to measure each phase voltage
and current. Acquire at least five separate voltage and current readings for each phase. Enter the
data on the Power Meter Sensor Function Checks form and compare with the power meter output
as displayed on the datalogger output (or PC display), power meter display (if present), and
logged data files. All power meter voltage readings must be within 2% of the corresponding
digital volt meter (DVM) reading. All power meter current readings must be within 3% of the
corresponding DVM reading.
14. Verify that the power meter is properly logging and storing data by downloading data to the PC
and reviewing it.
A-3
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Final
April, 2008
Appendix A2a. Power Meter Sensor Function Checks
Project Name: Office Power Location (city, state): New York City. NY
Date: Signature:
OUT Description:.
Elliott microturbine. Unit #6: Power output
Nameplate kW: 100
Expected max. kW: 100
Type (delta, wye): Wye Voltage, Line/Line: 480
Power Meter Mfr: Model:
Line/Neutral:
Serial No.:
Last NISTCal. Date:
Current (at expected max. kW): 121
.Conductor type & size:
Current Transformer (CT) Mfg: FlexCore Model:
CT Accuracy: (0.3 %, other): Ratio (100:5, 200:5, other): 400:5
606-401
277
Sensor Function Checks
Note: Acquire at least five separate readings for each phase. All power meter voltage readings must be within 2%
of the corresponding digital volt meter (DVM) reading. %Diff = (\PowerMeter/DVM\ -1) * 100
Voltage
Date
Time
(24 hr)
Phase A
Power
Meter
DVM
%Diff
Phase B
Power
Meter
DVM
%Diff
Phase C
Power
Meter
DVM
%Diff
Note: Acquire at least five separate readings for each phase. All power meter current readings must be within 3% of
the corresponding DVM reading.
Current
Date
Time
(24 hr)
Phase A
Power
Meter
DVM
%Diff
Phase B
Power
Meter
DVM
%Diff
Phase C
Power
Meter
DVM
%Diff
A-4
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Final
April, 2008
Appendix A2b. Power Meter Sensor Function Checks
Project Name: Office Power Location (city, state): New York City. NY
Date: Signature:
OUT Description:
Nameplate kW:
Elliott microturbine. Unit #6: Parasitic loads
Expected max. kW:_
Type (delta, wye): Wye Voltage, Line/Line: 480
Power Meter Mfr: Model:
Line/Neutral:
Serial No.:
Last NIST Cal. Date:
Current (at expected max. kW): 40
Current Transformer (CT) Mfg: FlexCore
.Conductor type & size:
Model:
606-201
CT Accuracy: (0.3 %, other): 0.2 %
Ratio (100:5, 200:5, other): 200:5
277
Sensor Function Checks
Note: Acquire at least five separate readings for each phase. All power meter voltage readings must be within 2%
of the corresponding digital volt meter (DVM) reading. %Diff = (\PowerMeter/DVM\ -1) * 100
Voltage
Date
Time
(24 hr)
Phase A
Power
Meter
DVM
%Diff
Phase B
Power
Meter
DVM
%Diff
Phase C
Power
Meter
DVM
%Diff
Note: Acquire at least five separate readings for each phase. All power meter current readings must be within 3% of
the corresponding DVM reading.
Current
Date
Time
(24 hr)
Phase A
Power
Meter
DVM
%Diff
Phase B
Power
Meter
DVM
%Diff
Phase C
Power
Meter
DVM
%Diff
A-5
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Final
April, 2008
Appendix A3. Method 2 Exhaust Gas Flow Rate Data Form
ProjJD: OfficePower TestJD: CntrlTest EquipJD: _Unit_6_Description: Elliott IQOkWMTG
Name (printed): Signature:
Date: Time: Run ID: Notch:
Elevation_247ft_ Ambient Pbar (psia)_
RunJD:
Stack Static Pg (psia)
Stack Abs. Ps (psia)
Duct dimensions: Round ID: 10"
Rectangular; L:
W:
Deqmvalent: 0.833ft Note: Deq =
LI: L5Jt ; diameters: 18
L2: 51 ; diameters: 6
2LW
L + W
Pitot ID#:
Coefficient (Cp):
L, = distance to L2 = distance to
upstream disturbance downstream disturbance
O ~*~~r " " " ^
Last calibration (date):
Conduct a total of three complete traverses at each notch and one idle setting during the baseline and candidate tests.
Fax completed data sheets to Southern for data entry at 919.806.2306.
Index
1
2
3
4
5
6
7
8
9
10
11
12
AP, "H20
Mean
Sqrt(AP)
Cyclonic
Angle, °
Temperature
°F / °C
Mean
Ts (Temp. +
460)
Notes:
A-6
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Final
April, 2008
Appendix A4. Horiba OBS-2200 Test Run Record
Project Name: OfficePower
Site ID: 110 E. 59-Street
Test ID: CntrlTest
Equip_ID: Unit 6
Date:
Run ID:
Name (printed):
Last 11-point Calibration Date:
Signature:
PEMS S/N:
Test Run Host facility operator name:
Start time (hh:mm:ss; use 24-hour clock): _
Filename:
End time:
Describe ambient conditions:
Wind speed (estimate):
Direction:
| Fair n Overcast D Precipitation
IMPORTANT: Refer to the OBS-2200 "..._b.csv" worksheets after each test run for the following
entries. Cell references are provided.
Enter "•/" if a parameter is acceptable, "Fail" if it is unacceptable. Discuss all "Fail" entries and indicate
whether the run is invalid because of them in the Notes below.
PEMS Zero and Span Drift Checks
Analyte
CO
C02
THC
NOX
Cal. Gas
Value and
Span (ppmv
or %)
2 % of Span
S if Zero drift
OK
(^±2% of
span
Cells D : 16)
4 % of Span
S if Span drift
OK
(^ ± 4 % of
span
Cells J3 : J6)
Parameter
Allowable ambient temperature range
(see b.csv worksheet Cells Ml 6 : EOF)
Allowable barometric pressure range
(see b.csv worksheet Cells N16 : EOF)
Allowable "Hangup" (NMHC
contamination) (see b.csv worksheet
Cell Z5)
Criteria
within + 10 °F (6 °C) for T^t < 80 °F (27 °C)
within + 5 °F (3 °C) for T^ > 80 °F (27 °C)
within+l"Hg(3.4kPa)
Enter expected THC concentration, ppmv as C
Enter 2 % of expected concentration
"Hangup must be < 2 % of expected concentration
^ifOK
NMHC contamination and background check < 2ppmv or < 2 % of cone. AP line leak check must be stable for 15 seconds at 3"
H2O. Mean Pbal within + 1.0" Hg of mean for all test runs. Mean T^ within + 10 °F of mean for all test runs if Tambis< 80 °F.
Mean T^t, within + 5 °F of mean for all test runs if T^ is > 80 °F. Drift = (Post-test span minus Pre-test span); must be < 4.0 %.
Notes:
A-7
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Final
April, 2008
Project Name: Office Power
Appendix AS: Load Test Run Log
Location (city, state) :New York City. NY
Date:
Signature:
Run ID:
Run Start Time:
Load Setting: %_
End Time:
kW
SUT Description: Elliott 100 kW MTG
Clock synchronization performed (Initials):
Data file names/locations (incl. path): File:
IMPORTANT: For ambient temperature and pressure, record one set of readings at the beginning and one at the
end of each test run. Also record at least two sets of readings at evenly spaced times throughout the test run.
B3-1. Ambient Temperature and Pressure
Time (24-hr)
Average
Amb. Temperature,
°F
Ambient Pressure
"Hg
PSIA = " Hg * 0.491
2.
3.
4.
5.
Permissible Variations
Each observation of the variables below should differ from the average of all observations by less than the maximum
permissible variation.
Acquire kW and Power Factor data from the power meter data file at the end of the test run. Transfer fuel flow data
from the Fuel Flow Log form. Obtain ambient temperature and pressure from Table A3-2 below. Obtain gas
temperature and pressure from Appendix B4.
Choose the maximum or minimum with the largest difference compared to the average for each value.
Use the maximum or minimum to calculate the %Diff for kW, Power Factor, Fuel Flow, and Ambient Pressure:
%Diff = ^Ma*oMin)-Averag/Average)* 100 Eqn. B3-1
For Ambient Temperature, Difference = (Max or Min)-Average
Variable
Ambient air temperature
Ambient pressure
Fuel flow
Power factor
Power output (kW)
Gas pressure
Gas temperature
Average
Maximum
Minimum
%Diffor
Difference
Acceptable?
(see below)
Permissible Variations
Measured Parameter
Ambient air temperature
Ambient pressure (barometric
station pressure)
Fuel flow
Power factor
Power output (kW)
Gas pressure
Gas temperature
MTG Allowed Range
+ 4°F
+ 0.5 %
+ 2.0%"
+ 2.0%
+ 2.0%
n/a
n/a
1C Generator Allowed Range
+ 5°F
+ 1.0%
n/a
n/a
+ 5.0%
+ 2.0%*
+ 5°F*
"Not applicable for liquid-fueled applications < 30 kW.
*Gas-fired units only
A-8
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Final
April, 2008
Appendix A6: Fuel Consumption Determination
Project Name: Office Power
Location
(city, state): New York, NY
Date:
Signature:
Test Description: Elliott MTG
MeterAMfg:
Meter BMfg:
Run_ID:
Model:
Model:
Load, % or kW:
S/N:
S/N:
This procedure assumes that each of the two gas meters (Meter A and Meter B) run at approximately the same rate,
or about 10 standard cubic feet per minute (scfrn). Collection of readings every 50 scf will allow about 5 minutes
between readings at each meter. This will allow the observer to alternate between the two meters with reasonable
confidence.
1. Start the test run by logging an initial gas meter reading and the exact time of day to 0.1 seconds. Start with
Meter A. The initial reading consists of the last 3 or 4 odometer digits. The last digit to the right on the meter reads
as "0.1" Ccf, or 1/10 of 100 scf. This means that each integer reading amounts to 10 scf. The odometer wheel to the
right of the last digit has a hash mark which, when it pass by the scale arrow, indicates the exact instant of the
integer reading. Log that time of day by holding a timepiece next to the odometer and watching for the hash mark.
Try to be as consistent as possible in determining where the hash mark crosses the scale arrow.
2. Add 0.5 (or 50 scf) to the initial Meter A odometer reading. This will be the reading at which to collect the
second time of day. Fill in the rest of the Meter A odometer columns (at least 9 entries) in 0.5 increments.
3. About 2 minutes after collecting the initial Meter A readings, collect the same data from Meter B. Fill in the
Meter B odometer columns similar to Meter A.
4. About 5 minutes after collecting the initial Meter A readings, watch its odometer for the odometer reading you
entered at step 2. Record the exact time of day.
5. About 5 minutes after collecting the initial Meter B readings, watch its odometer for the odometer reading you
entered at step 2. Record the exact time of day.
6. Continue until at least 9 complete readings have been collected from each meter.
9. Perform the calculations as indicated. Calculate the total elapsed time as the difference between the final and
initial times or as the sum of the elapsed times. Calculate and enter the total rate in standard cubic feet per minute
(scfm) for each of the 3 test runs onto Appendix AXX. Maximum permissible variation for all three runs is + 2.0 %.
Ref. (n)
1
2
3
4
5
6
7
8
9
Meter A
Odometer
(scf)
Tot. Used
(Final-
Initial)
Rate A, scfm
(Tot.used/dec.niin.)
Time
Total elapsed,
mm:ss
Total elapsed,
decimal minutes
Elapsed
(Time, - Tim^j)
Rate B, scfm
(Tot.used/dec.niin.)
Meter B
Odometer
(scf)
Tot.Used
(Final-
Initial)
Time
Total elapsed,
mm:ss
Total elapsed,
decimal minutes
Rate Tot, scfm
(RateA + RateB)
Elapsed
(Time,, - Time^j)
A-9
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Final
April, 2008
Appendix A7: Fuel Sampling Log
IMPORTANT: Use separate sampling log and Chain of Custody forms for each sample type (gas fuel, liquid fuel,
heat transfer fluid).
Project Name: OfficePower
Date:
SUT Description:,
MTG array
Location (city, state): New York City. NY
Signature:
Run ID: Load Setting: % kW_
Fuel Source (pipeline, digester): pipeline
Sample Type (gas fuel, liquid fuel, heat transfer fluid):
Fuel Type (natural gas, biogas, diesel, etc.):
gas fuel
natural gas
Note: Obtain fuel gas sample pressure and temperature from gas meter pressure and temperature sensors or
sampling equipment.
Gas Fuel Samples
Date
24-hr
Time
Run ID
Canister
ID
Initial
Vacuum,
"Hg
Sample Pressure
(from gas meter
pressure sensor or
sampling train
pressure gage)
Sample Temperature
(from gas meter
temperature sensor
or estimated)
A-10
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Final
April, 2008
Appendix A8: Sample Chain-of-Custody Record
Important: Use separate Chain-of-Custody Record for each laboratory or sample type.
Project Name: Office Power Location (city, state): New York City. NY
Test Manager/Contractor Southern Research Institute Phone: 919.282.1050 Fax: 919.282.1060
Address: 5201 International Drive City,State / Zip: Durham. NC 27712
Originator's signature: Unit description: MTG array
Sample description & type (gas, liquid, other.):
Laboratory: Empact Analytical Phone: 303.637.0150
Address: 365 S. Main City: Brighton
Fax: 303.637.7512
State: CO Zip: 80601
Sample ID
Bottle/Canister ID
Sample Pressure
Sample Temp, or
TAvg, (°F)
Analyses Req'd
ASTM 01945,03588
Relinquished by:_
Received by:
Relinquished by:_
Received by:
Relinquished by:_
Received by:
Date:_
Date:_
Date:_
Date:_
Date:_
Date:
Time:.
Time:.
Time:.
Time:.
Time:.
Time:
Notes: (shipper tracking #, other)
A-ll
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Final
April, 2008
Appendix B
Elliott Microturbine Specifications
&
l/Jl
ELLK
MICROTURBINES
100kWCHP
Microturbine
Elliott Energy Systems, Inc. has been
designing and supplying microturbines
since 1997. Our experience has made us
a leader in microturbine technology.
Located in Stuart, Florida. USA.
The TA100 CHP is packaged as an
efficient combined heat and power (CHP)
genset. Our Microturbine CHP system is
capable of producing 100kW of electrical
energy and 172KW of thermal power per
hour. Cogeneration usage can consist of
hot water, absorption chiller or drying
system applications. Depending upon the
user application, overall total thermal
efficiency could be greater than 75%.
Main Features:
Rated Power Output
Electrical
Thermal
Noise
Electrical Data
Parallel Ready
Voltage Output
Amps
Frequency
Output Circuit
Operating Mode
100kW@ 0.8PF
at 59°F/15°C, Sea Level
172kW/587,000 BTU/hr
Outdoor <62 dBA @ 10 m
Indoor <75 dBA@ 1 m
4007 480 VAC
200 Max
501 60 Hz
4-Wire Wye
Island & Grid Connect)
Standard Equipment:
• Integral Gas Compressor
• Integral Heat Recovery Unit
(Stainless Tube & Copper Fin)
• Remote Interface
RS485/ Modbus
• Automatic Voltage Regulation
• Battery Charger
Single Stage Dry Type Air Filter
1 Corrosion Resistant Hardware
• Digital LCD Touch Panel
• System Protection Including:
n Under and Over Voltage
n Under and Over Frequency
a Over Current, Over Temperature
• Optional Outdoor Kit (NEMA 3R, IP 44)
• Battery Start
• CE Certified
Compressor
The compressor is a rugged stainless
steel radial flow design. The
approximate pressure ratio is 4 to 1.
Combustor
Combustor is designed with the aid of
advanced computational fluid
dynamics capabilities and precision
tested with high accuracy flow systems
to provide reliable starting, robust
operation during onload/ offload,
extended life, and low NOx and CO
over the entire operating range.
High Speed Alternator
The electric power is generated
through a 4 pole, permanent magnet
alternator rotating within an oil cooled
stator assembly. The stator assembly is
energized as a motor during initial
start-up reducing the need for auxiliary
starting hardware.
Turbine
The radial super-alloy turbine provides
design margin and long life capability to
provide energy to drive both the
compressor alternator.
Heat Exchanger
The heat exchanger is an air to liquid
tube and fin counter current flow
design, fired by the exhaust gas. The
tube and fin materials have been
selected to provide long life, maximum
thermal energy recovery and allows for
potable water applications. The outlet
liquid temperature is dependent upon
inlet liquid temperature and liquid flow.
Power Electronics
The output from the alternator is
converted into 480 or 400 VAC. 60 or
50 Hz. depending upon the needs of
the end-user.
Control System
The control system provides automatic
control of the CHP System, Turbine
and Engine protection features as well
as complete control of engine, starting,
speed, safety systems , and outside
communications.
Conforms to:
• UL Standard 2200
• UL Standard 1741
• EU Directive 90/396/EEC
C€
0063 /07
' Photo is shown with exhaust flange
©2007 by Elliott Energy Systems, Inc. All Rights Reserved
EESI #51 Rev. 3
B-l
-------
Final
April, 2008
Appendix B, Continued
Elliott Microturbine Specifications
TA100 CHP Specifications
Performance:
Electrical Output
Output (@ ISO) 100kWnet
105 kW gross
Maximum Block Loading 100%
Minimum Load OkW
Efficiency* 29%(+/-1)LHV
THD < 3%
Voltage Regulation +/- 2%
Fuel Consumption (ISO Rated
Power)
Natural Gas: 22 SCFM/
0.62 m3/min
(940 BTU/ SCF)
362 kW {@ 1,235,000 Btu/ hr.) LHV
Heat Rate 12,355 BTU/ kWh
Thermal Output (Hot water)
172 kW / 587,000 Btu/ hr.
Water Inlet Temp 120°F/49°C
Water Outlet Temp 140°F/60°C
Flow 60 GPM/ 3.8 L/s
Total System Efficiency* >75%
" No! Including Gas Compressor
Engine
Manufacturer Elliott Energy
Systems
Model TA-100CHP
Type Recuperated Gas Turbine
Pressure Ratio 4 to 1
Emissions, Natural Gas (Typical)
CO: 20PPM@15%O2
25.4 mg/MJ
25.0 mg/rn3@ 15% O2
0.77 IDS/ MWhr
0.243 grams /bhp hr
0.059 Ibs /MMBTU
NOx: 22PPM@15%02
48.7 mg/MJ
45 mg/m3@ 15% O2
1.48 Ibs/MWhr
0.467 grams /bhp hr
0.113 Ibs/MMBTU
Exhaust Gas Temperature
Heat Recovery Mode 180T/
82°C
Full HRU Bypass 560°F; 293"C
Batteries 24VDC min.
Two 12 volt, Group 27, lead acid,
maintenance free - 105AN nominal
Total Weight with Enclosure:
Indoor: 4,100 Ib./1,860 kg
Outdoor: 4,500 Ib./ 2,040 kg
Engine Inlet Air
Cooling System
Alternator Oil Cooled
Power Electronics Air Cooled
Enclosure 2,400 CFM/ 1.13 m3/s
Exhaust System
Outlet Size 10" Diameter
Max. Back Pressure 5" water column
1.2 kPa
Exhaust Gas Flow 1,500 SCFM
0.71 Nm3/s ,
Fuel '
Fuel Type Natural Gas
Pressure Required 0.5 - 5 PSIG
3.4 - 34.5 kPa
Oil System
Oil Type Mobil SHC 824
Capacity 5 US gal. (19 L)
Oil Filter Spin On Type, 3 Micron
Eng ne
\ Exhaust Stack
\\
*m
I,3
" All figures at ISO 59°F' 15°C Enclosure! /•
unless otherwise noted Exhaust f^
*H
mmf^m m ms*^^^
xl
ma^
'/L.
2'FNPI
Water _^
Z'FNPT
l;rnNPT
r
i
r
/
7
/
\
\
CD
6
n?t
/,
/
M
'/
H
A f r
\ 1.65m' /
/ \ / \
I
CD
M r— h_ J
M3.0} Fuel Supply /
T MfJPT
C3
\
' 1 ' — 1 f1" — "-"
~^j(~-_i_ro,k hit Poms L-jKJJj--
.!
Km
d?fi1i"
|
. - Power
2TNPTHUB
Riclgid
MIOI
MICROTURBINES
Left Side View
For more information please contact:
Elliott Energy Systems, Inc.
Sales & Marketing
ees.sales@elliottmicroturbines.com
©2007 by Elliott Energy Systems, Inc. All Rights Reserved
2901 S.E, Monroe St.
Stuart. FL 34997 USA
Tel:772-219-9449
Fax:772-219-9448
Website: www.elliottmicroturbines.com
The specifications in this catalogue are subject to change without prior notice
EESI #51 Rev. 3
B-2
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