HomeMy WebLinkAboutRenewable Energy Report Task 3.2.5— Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5—Pre-Demonstration Summary Report j
v
Draft Report
Pre-Demonstration Summary Report
NOVEMBER 7, 2003
Renewable Energy Research Program
To Make Renewables Part of California's
Affordable and Diverse Public Power System
CONTRACT # 500-01-042
Commission Project Manager: Val Tiangco
Contractor Project Manager: Fred Weiner—SFPUC
Contractor Program Manager: Ray Dracker -CRS
Subcontractor: Scott Haase- McNeil Technologies
HHWP-042, Del 3.2.5, 11-03
Task 3.2.5 —Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5— Pre-Demonstration Summary Report
Table of Contents
1 Introduction................................................................................................................................... 2
2 Host Site Selection........................................................................................................................ 2
3 BioMax System Generation Characteristics................................................................................. 2
4 Interconnection Requirements Including Permitting....................... ............__...............__...... 2
5 Fuel Supply................................................................................................................................... 3
6 System Financing.......................................................................................................................... 3
Index of Figures
Figure1. Suggested Site Layout........................................................................................................... 4
Index of Appendices
Appendix A. Site Specifications from Community Power Corporation...........................................A-1
Appendix B. BioMax 15 Demonstration Site Requirements—Truckee Donner Public Utility District
............................................................................................ ........................................................ B-I
Appendix C. Interconnection Agreement for Net Energy Metering................................................. C-1
HHWP-042, Del 3.2.1.1, 10-03 I
Task 3.2.5— Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5— Pre-Demonstration Summary Report
I INTRODUCTION
This Draft Report provides preliminary data, analysis, conclusions, and recommendations regarding
the information necessary to proceed with the biomass technology demonstration project.
The goal of Task 3.2.5, Micro Scale Technology Demonstration: Project Development and
Engineering, is to coordinate all aspects of the technology demonstration project. The team will take
the results and information developed under the previous tasks on this project and plan a suitable
demonstration project in the TDPUD service territory. The project will seek to document the costs,
energy generation, economic performance, technical performance, emissions and other criteria
associated with running the BioMax technology developed by Community Power Corporation
(CPC) of Littleton, Colorado in a small load center. To accomplish the task goals McNeil will 1)
coordinate with the Recreation Center, CPC, and TDPUD to analyze specific details of the project
(host site needs, utility interconnection agreements, safety, fuel supply, operating requirements,
permits, etc.), 2) conduct engineering design studies and technology modifications as needed, and 3)
make arrangements for system procurement, financing and installation.
In furtherance of these objectives, McNeil shall 1) make all arrangements to locate a host site for the
demonstration project and coordinate between the host site, the utility, and CPC, 2)work with CPC,
the host utility, power marketers and others to ensure that the generator characteristics of the
BioMax system match as closely as possible the high value requirements of the system, 3) evaluate
interconnection requirements, including safety, equipment needs, buy-back rate, provisions for net
metering, and assist the host as necessary in procuring permits, and 4) work with all parties to
deteinvne how the system and technology demonstration project will be financed, including, as
appropriate, the use of California Energy Commission funds. McNeil will also prepare the final
agreements for the technology demonstration signed by all parties and a pre-demonstration summary
report.
2 HOST SITE SELECTION
Site selection for the 15-kW unit has been completed. The BioMax will be demonstrated at the Truckee
Recreation Center. An agreement between CPC and the host utility has been drafted and presented in
association with another deliverable under this task. Site requirements for the BioMax system are
provided in Appendix A.
3 BIOMAX SYSTEM GENERATION CHARACTERISTICS
Information about the BioMax system is provided in Appendix B. Fabrication is well on its way to
completion and testing of the system is expected soon, if it has not already been completed. More details
on fabrication and internal testing is provided in the deliverable for 3.2.5c.
4 INTERCONNECTION REQUIREMENTS INCLUDING PERMITTING
The energy from the biomass technology demonstration project will be accepted by TDPUD under the
terms of a net metering interconnection agreement. A prototype of such an agreement is provided as
Appendix C.
HHWP-042, Del 3.2.1.1, 10-03 2
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5— Pre-Demonstration Summary Report
5 FUEL SUPPLY
The system will use approximately 400 lb/day of fuel, assuming 8 hours per day of operation(see
Appendix A). TDPUD will use wood fuel from their line clearance operations to the extent possible to
reduce fuel supply costs and provide an outlet for some of the material they generate internally.
6 SYSTEM FINANCING
The fabrication of the system is being completed with CEC funds. We are presently compiling cost
information for the Balance of System components including slab, building, heat exchanger,
electrical and ducting, construction and interconnection gear. We will then attempt to locate a local
source for these funds. TDPUD will assist in locating additional funding.
HHWP-042, Del 3.2.1.1, 10-03 3
Task 3.2.5 — Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5— Pre-Demonstration Summary Report
Appendix A. Site Specifications from Community Power Corporation
Fuel & Fuel Processing
1) Wood source
a. Wood should be chipped rather than shredded for use as fuel. Long, fibrous or shredded
pieces of wood may get hung up either in the feeding mechanism or the gasifer.
2) Size and sorting requirements
a. Wood chips should be sorted to eliminate oversize pieces; this can be accomplished with
the integrated sorting screen in our fuel daybin or with a supplemental system.
b. Sawdust and undersize chips do not need to be removed as long as they don't comprise
more than 10-15% of the wood chips by weight.
c. An expanded metal screen can be used for sorting overs
i. We use a'/4 No. 16 Ryex expanded metal screen which can be purchased in 4' x
8' sheets from Ryerson.
ii. Our technique for screening involves a metal screen framework insert for the
daybin feeder with a vibrator attached to the screen.
3) Wood type and content
a. Suitable wood species are Lodgepole Pine, Ponderosa Pine, Douglas Fir or similar
species; check with CPC to confirm suitability.
b. Bark content is not a problem as long as it does not comprise more than about 10-15% of
the wood chips by weight.
c. Care should be taken to avoid mixing dirt and stones in with the wood chips as these can
cause the feeding mechanisms or gasifier to malfunction. These materials can mix with
the wood if the wood is stored on the ground and scooped up with a front end loader.
4) Moisture content
a. Fresh cut wood needs to be air dried to about 20-25% moisture content before it can be
used on the SMB system
b. CPC's fuel feeder/drier mechanism uses waste heat from the cooling system to perform
additional wood drying; it is expected to be able to perform additional drying to reduce
the moisture content from about 20-25% down to 10-15% which is ideal for the gasifier
system.
c. At CPC we are able to spread the wood chips in a thin layer on a concrete pad for
effective passive solar drying. It takes 1-2 days to dry chips in this manner depending on
season and weather.
d. Other means of performing preliminary drying can be explored in consultation with CPC.
HHWP-042, Del 3.2.1.1, 10-03 A-1
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5—Pre-Demonstration Summary Report
e. Moisture content can be measured with a small inexpensive hand held meter and fuel
moisture should be checked as frequently as required to assure adequate drying of
incoming fuel and proper(drying) function of the feeder/drier subsystem.
5) Storage
a. Wood chips should be stored in a covered location away from the effects of rain or snow.
b. Chips with high moisture content, which are stored in sealed containers or large piles,
may ferment or even spontaneously combust.
c. Chips should be stored with a reasonable amount of air circulation.
6) Daybin storage
a. The system daybin will hold about 3-6 hours of fuel depending on power delivery and
fuel consumption rates.
b. The daybin can be loaded either manually or with a bucket loader.
c. The daybin is attached to an automated feeder which delivers and meters fuel
automatically to the gas production module.
7) Consumption rates
a. System fuel consumption will be approx. 3 lbs/hr/kWe
b. Total consumption will be approximately 400 lbs/day assuming 15kWe average x 8 hrs.
Ventilation
I) System should be operated in a well ventilated location such as a carport or open shed
2) If air flow is restricted the engine exhaust should be vented to the outside; engine exhaust pipe
runs should be kept as short as possible to avoid backpressure and efficiency losses
3) Redundant CO detectors should be in place to protect against any buildup of carbon monoxide
4) In the event of an emergency shut down the systemm may emit small quantities of smoke.
Noise
1) The gas production module and feeding equipment are relatively quiet. Only the intermittent
sound of electrical motors and vibrators can be heard
2) The genset has critical grade sound attenuation; noise levels should be <70dB at 7 meters.
3) A shed that has sound attenuating walls will help dissipate noise.
Electrical
1) Access to on-site 120 VAC single phase is needed for cleanup systems, tools, and possibly
diagnostic equipment
2) Power delivery from the unit will be to a dedicated load distribution panel.
3) Specific on site requirements may include a transformer or transfer switch.
HHWP-042, Del 3.2.1.1, 10-03 A-2
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5— Pre-Demonstration Summary Report
4) Routing of power cables should be considered before the system is installed to avoid wiring runs
that may create a hazard (under foot, etc.)
Propane
1) The system requires LPG (can take liquid or vapor); needs to be high pressure(100 psi GA)
2) Location of tank& delivery lines need to be installed in compliance with local codes.
3) LPG and delivery lines are supplied by the site; the SMB genset has a '/NPT female inlet for
LPG hookup
4) Site is required to supply an in line filter/strainer at the entry to the genset
5) LPG useage rate approx 2 kg per startup cycle
Layout
1) The suggested site layout (Figure 1) is based on a three contiguous room building design
with suggested dimensions for a warming hut, Biomax equipment room and wood chip
storage shed. The warming but layout and dimensions are strictly for sake of illustration
since nothing is known about the requirements for this area.
1) Equipment should be mounted on a level pad with sufficient strength to support the weight of the
units (see below); the pad should be smooth enough to move the units on self-contained wheels
2) Some mounting attachments to the pad may be required if the units show any tendency to creep
during operation
HHWP-042, Del 3.2.1.1, 10-03 A-3
Task 3.2.5—Micro Scale'Technology Demonstration: Project Development and Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
SUGGESTED LAYOUT MCNEIL SYSTEM
30 0 —
WARMING .,_..,. u'AKi ,a
I;
WIT AR
r� ey HG I' 1
BIOMAX crcow'
_a,O ROOM 2.,cnevr:a fftOElt fNtYl:R � — i f
as
o.,
CM
I — - ► A r- �.- r rusr ,«I y�
qq WOOD CI{IB 6R'ORAGE
5
Figure 1. Suggested Site Layout
A-4
Task 3.2.5 —Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
Logistics
1) Forklift
a. Required for lifting units off of truck and into final operating locations
2) Four pieces
a. Genet—I ITT x 38"W x 54"H including wooden skid; 2000 lbs
b. Gas production module—96"L x 56"W x 78"H; built in forklift pockets; 1500 lbs
c. Feeder daybin— 130"L x 48"W x 73"H; no skid; 1000 lbs
d. Drier assembly— 144"L x 60"W x 36"H; no skid; 600 lbs
Safety
I Need redundant CO monitors in area
2) Need fire extinguishers for emergencies
3) Need safety glasses for visitors
4) Need signs for limiter(access or use areas
5) Need particulate masks fitted to operators for cleanup operations
6) Above safety equipment will be supplied by CPC and safety training will be conducted by CPC's
field engineer.
Installation & Field Support
1) A dedicated CPC field engineer will support installation and system commissioning on site.
2) The field engineer will also perform on site training for system operators.
3) Operation and maintenance documentation will be supplied with the system.
4) Installation is expected to take one day.
5) System commissioning is expected to take one to two days depending on problems.
6) On site training is expected to take two days.
7) CPC's lead electronicsengineer (Dusty Duncan) will be the customer's point of contact for the
duration of the project
a. Customer will be given a cell phone#to reach the field engineer at any time; other
members of CPC can be reached during normal business hours
b. Response time t respond to a call will be within 24 hours
c. Field engineer will first try to fix any problems by working with the on site operator
d. Response time to fix a problem on site will be within 4 working days from failed attempts
to fix the problem through phone consultations
e. Some spare parts will be supplied with the unit; other spares will be stockpiled at CPC's
facilities.
A-5
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
Maintenance
1) An industrial vacuum system will be supplied for removing charcoal and ash from the system
a. Vacuum has HEPA rated filters which remove particulates as small as 0.3 microns with
99.999% efficiency
b. Vacuum collects material into a drum lined with a plastic trash can liner; liner can be tied
up and disposed through normal waste channels
c. Two drums collect solid wastes during the run
i. Char bin below the reverse flow inertial separator (char pot)
it. Filter drum
d. Extraction method(char bin)
i. Wait until system is cooled down (minimum 12 hrs)
ii. Leave valve open above the char bin
iii. Remove rupture disk and shield
iv. Turn PGM (engine genet) on for 1 minute to purge residual gases from the
cooling and cleanup system
v. Detach the drum from the valve
vi. Clamp air inlet adaptor to the 3 inch opening and vacuum adaptor to the 4 inch
opening
vii. Turn on vacuum for approximately 30 seconds or until the bin is empty
viii. Inspect and replace the graphoil gasket between the valve and char bin if
necessary.
ix. Extract the char fines from the filter vessel (see below)
x. Remove extraction fittings, replace the rupture disk& shield and reattach the bin
to the valve fitting
e. Extraction method(filter vessel)
i. Wait until system is cooled down (minimum 12 hrs)
ii. Perform extraction while the char bin is removed from the char pot and the valve
is opened and after the system is purged
iii. Remove rupture disk and shield
iv. Clamp vacuum adaptor to the 4 inch opening
v. Operate the vibrator motor on the bottom of the drum during extraction
vi. Turn on vacuum for approximately 30 seconds or until the bin is empty
vii. Replace the rupture disk and shield
viii. Make sure to complete the char bin closure steps
2) No liquid residues or sticky tar residues are created or collected for removal.
A-6
Task 3.2.5— Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 -Pre-Demonstration Summary Report
3) Typical daily routine
a. Empty char bins with vacuum
b. Char& fines production approx. 10-20 lbs/day
c. Review data from previous run
i. if dP across the heat exchangers was > open for inspection and cleaning
ii. if dP across gasifier was > open gasifier for inspection and cleaning
4) Typical weekly routine
a. Open and inspect gasifier; remove any clinkers (stones or lumps of fused ash) and
vacuum grate
b. Inspect char air injector; open any clogged holes
c. Inspect and vacuum soot from heat exchanger entrances
d. Inspect bag filter & safety filter
e. Pressure test system
5) Typical biweekly routine
a. Change engine oil approximately after every 100 hours of operating time
b. Inspect feeder dryer and remove any sawdust buildup
6) Monthly inspection
a. Remove gasifier and perform full inspection, removing grate and injector
b. Full inspection of both heat exchangers
c. Individual component pressure test
d. Full inspection of filter bag, internal cage and vessel interior
e. Remove and inspect engine intake components
f. Clean safety filter
A-7
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
Appendix B. BioMax 15 Demonstration Site Requirements—Truckee Donner Public Utility
District
Background
This project will demonstrate the operation of the BioMaxTM, a new, small modular biopower system
under development by Community Power Corporation (CPC) of Littleton, Colorado. The on-going
development of this technology is the result of contributions by the US National Renewable Energy
Laboratory, USDOE, California Energy Commission, the US Forest Service, Community Power
Corporation, and other organizations.
Gas The goal is to develop a new line of small modular
Pro uoton ,.
biopower systems for the 21"Century suitable for
r o distributed generation applications and capable of using a
Mwulle
Motlule
variety of woody biomass fuels including forest and
agricultural residues to generate power and heat in an
environmentally acceptable manner. CPC has designated
TM
this line of modular biopower systems as the BioMax
# t� with peak power modules from 2.5 kWe to eventually
100 kWe. The BioMax system that will be demonstrated
Power = under this project with the Truckee Donner Public Utility
Generation ,i:�+�Sv' �
District (TDPUD) and will produce a peak power on
wood-gas of 15 kWe.
The BioMax 15 is now at a pre-commercial stage of development. This field trial will reveal ways to
strengthen the system and provide valuable inputs to guide and accelerate the product improvement
and commercialization process.
Objectives of the Field Demonstration
• Conduct a field-based demonstration of the BioMax 15 to generate power(and possibly) heat
to support operations at an on-grid facility
• Monitor the operation and performance of the BioMax 15 to provide inputs for product
improvement
• Promote the use of small modular biopower systems for on and off-grid applications in the
State of California
• Determine the economics of operating small modular biopower systems in distributed
generation applications
• Measure and compare the emissions of the BioMax system with other distributed generation
power systems of the same size
Demonstration Site Characteristics
Location: TDPUD service territory
Accessibility: Highly accessible,paved road, close as possible to service center
Loads:
Dedicated load:
B-1
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
Up to 15 kW, single or three phase, daytime load, no motor larger than 10 hp
Parallel with Grid: No restrictions
Hours of Operation: Up to 8 hours per day
Applications:
Ideal: Grid parallel with main Truckee/Donner service center
Possible: Water pumping station, secondary service center, rural enterprise, e.g., wood
working shop, green house, etc.
On-site O&M Labor
Two persons to be trained and capable of independent operation and maintenance of the BioMax
system. One person assigned as prime attendant and one person as back-up.
Daily O&M: up to I hour of attendant labor for:
• wood chip loading and sorting
• component check list
• periodic vacuuming of filters
• disposal of bags of char/ash from filters (approx. 1, 40 gal. garbage bag each day)
• operational data downloading from control system
Weekly O&M: I hour of attendant labor for wood chip preparation and handling (assumes use of 4
cylinder chipper with wood scraps on site)
Facility/Equipment Requirements
Shelter: BioMax System: Simple building, min. 20ft x 30ft,paved floor, min. 12 ft clearance,
powered roof ventilator, sliding doors front and rear. Storage shelves and cabinet for tools and
maintenance supplies
Wood Chipping, Storage and Handling: Periodic use of 4 cylinder wood chipper, covered area for
wood chip storage (20 ft. x 20 ft.)
Responsibilities of Parties
Community Power Corporation will provide one BioMax 15 including the Gas Production Module,
Power Generation Module, Dry/Feeder Module and Grid Interface Module. CPC will transport and
install the system,provide on-site training for attendants and will provide full system warranty and
technical support throughout the duration of CPC's contract.
The Site Sponsor will provide everything required to house, connect, fuel, operate and maintain the
BioMax system on site during the period of the field trial. Any thermal applications (CHP) and
emissions measurements will be the responsibility of the Site Sponsor.
B-2
Task 3.2.5— Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
Appendix C. Interconnection Agreement for Net Energy Metering
Interconnection Agreement for Net Energy Metering
(customer-generator) and Truckee Donner Public Utility
District (District) referred to collectively as "parties"and individually as "party,"agree as follows:
1. BIOMASS GENERATING FACILITY
1.1 Address:
1.2 Facility will be ready for operation on or about:
1.3 Location of District designated switching center:
1.4 Location of District customer service center:
1.5 Operating option—Customer-generator has elected to operate its biomass generating
facility in parallel with District's distribution facilities. The biomass generating
facility is intended primarily to offset part or all of the customer-generator's own
electrical requirements.
2. PAYMENT FOR NET ENERGY
2.1 In the event the energy generated by the facility exceeds the energy consumed on the
customer-generator's premise during any billing period,payment for net as-available
energy delivered to District shall be determined by an average, non-time-of-delivery
price.
2.2 District reserves the right to apply the value of District's purchase of energy toward
any bill to customer-generator for electric service by District to customer-generator at
the location in Section 1.1. Customer-generator shall pay any amount owing for
electric service provided by District in accordance with electric rate schedule D-NM
[schedule name may need to be changed]. Nothing in this Section 2.2 shall limit
District's rights under applicable tariff schedules.
C-1
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
3. PRICE FOR NET ENERGY
3.1 On and after the date District gives its written approval for parallel operation pursuant
to Section 5.4, District shall pay customer-generator for net as-available energy at
prices authorized from time to time by the District and which are derived from
District's monthly average non-firm electric energy price the District pays during the
applicable month.
4. INTERRUPTION OR REDUCTION OF DELIVERIES
4.1 District shall not be obligated to accept or pay for, and may require, customer-
generator to interrupt or reduce deliveries of as-available energy: (a) when necessary
in order to construct, install, maintain, repair, replace, remove, investigate or inspect
any of its equipment or part of its system; or (b) if it determines that curtailment,
interruption or reduction is necessary because of emergencies, forced outages, force
majeure or compliance with prudent electrical practices.
4.2 Whenever possible, District shall give customer-generator reasonable notice of the
possibility that interruption or reduction of deliveries may be required.
4.3 Notwithstanding any other provision of this agreement, if at any time District
determines that either (a) the facility may endanger District personnel or (b) the
continued operation of customer-generator's facility may endanger the integrity of
District's electric system, District shall have the right to disconnect customer-
generator's facility from District's electric system. Customer-generator's facility shall
remain disconnected until such time as District is satisfied that the condition(s)
referenced in (a) or(b) of this Section 4.3 have been corrected.
5. INTERCONNECTION
5.1 Customer-generator shall deliver the as-available energy to District at the utility's
meter.
5.2 Customer-generator shall pay for designing, installing, operating and maintaining the
biomass generating facility in accordance with all applicable laws and regulations and
shall comply with District's Appendix A [will need to be a different Appendix,
written for the biomass facility—as such it is not attached in this specific document,
which is attached hereto.
C-2
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
5.3 The customer-generator shall install adequate protective devices to protect his
equipment from overcurrent, over or under voltage, switching, transients, and
lightning.
5.4 District shall furnish and install a standard watt-hour meter. Customer-generator shall
provide and install a meter socket and related equipment.
5.5 Customer-generator shall not commence parallel operation of the generating facility
until written approval of the interconnection facilities has been given by District.
Such approval shall not be unreasonably withheld. District shall have the right to have
representatives present at the initial testing of customer-generator's protective
apparatus.
5.6 The customer-generator shall insure the delivery of only 60-Hz electric power into the
District's system and at the designated service voltage.
5.7 Upon notification, the customer-generator will within ten (10) days from notification
eliminate any radio or television interference and/or any other power quality
problems that may arise from the customer-generator's biomass generation.
6. MAINTENANCE AND PERMITS
6.1 Customer-generator shall: (a) maintain the biomass generating facility and
interconnection facilities in a safe and prudent manner and in conformance with all
applicable laws and regulations including,but not limited to, District's Appendix A
[as appropriate] and (b) obtain any governmental authorizations and permits required
for the construction and operation of the biomass generating facility and
interconnection facilities. Customer-generator shall reimburse District for any and all
losses, damages, claims, penalties or liability it incurs as a result of customer-
generator's failure to obtain or maintain any governmental authorizations and permits
required for construction and operation of customer-generator's generating facility.
7. ACCESS TO PREMISES
7.1 District may enter customer-generator's premises: (a) to inspect at all reasonable
hours customer-generator's protective devices and read or test meter; and (b) to
disconnect, without notice, the interconnection facilities, if, in District's opinion, a
hazardous condition exists and such immediate action is necessary to protect persons,
or District's facilities, or property of others from damage or interference caused by
C-3
Task 3.2.5— Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
customer-generator's biomass facilities, or lack of properly [word in original
agreement was property—think it should be properly] operating protective devices.
8. INDEMNITY AND LIABILITY
8.1 Each party as indemnitor shall defend, save harmless and indemnify the other party
and the directors, officers, employees and agents of such other party against and from
any and all loss, liability, damage, claim, cost, charge, demand, or expense (including
any direct, indirect, or consequential loss, liability, damage, claim, cost, charge,
demand or expense, including attorneys' fees) for injury or death to persons including
employees of either party and damage to property including property of either party
arising out of or in connection with(a) the engineering, design, construction,
maintenance, repair, operation, supervision, inspection, testing, protection or
ownership of, or (b) the making of replacements, additions,betterments to, or
reconstruction of, the indemnitor's facilities;provided, however, customer-
generator's duty to indemnify District hereunder shall not extend the loss, liability,
damage, claim, cost, charge, demand or expense resulting from interruptions in
electrical service to District's customers other than customer-generator. This
indemnity shall apply notwithstanding the active or passive negligence of the
indenmitee. However, neither party shall be indemnified hereunder for its toss,
liability, damage, claim, cost, charge, demand or expense resulting from its sole
negligence or willful misconduct.
8.2 Notwithstanding the indemnity of Section 8.1, and except for a party's willful
misconduct or sole negligence, each party shall be responsible for damage to its
facilities resulting from electrical disturbances or faults.
8.3 The provisions of this Section shall not be construed to relieve any insurer of its
obligations to pay any insurance claims in accordance with the provisions of any
valid insurance policy.
8A Except as otherwise provided in Section 8.1, neither party shall be liable to the other
party for consequential damages incurred by that party.
8.5 If customer-generator fails to comply with the insurance provisions of this agreement,
if any, customer-generator shall, at its own cost, defend, save harmless, and
indemnify District, its directors, officers, employees, agents, assignees and successors
in interest from and against any and all loss, liability, damage, claim, cost, charge,
demand or expense of any kind or nature(including attorneys' fees and other costs of
litigation) resulting from the death or injury to any person or damage to any property,
including the personnel and property of District, to the extent that District would have
C-4
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
been protected had customer-generator complied with all such insurance provisions.
The inclusion of this Section 8.5 is not intended to create any express or implied right
in customer-generator to elect not to provide any such required insurance.
9. INSURANCE
9.1 Customer-generator shall maintain, during the term of this agreement comprehensive
personal liability insurance with a combined single limit of not less than one-hundred
thousand dollars ($100,000) for each occurrence.
9.2 Such insurance required in Section 9.1 shall, by endorsement to the policy or policies,
provide for thirty(30) calendar days written notice to District prior to cancellation,
termination, alterations, or material change of such insurance.
9.3 District shall have the right to inspect or obtain a copy of the original policy or
policies of insurance.
9.4 Customer-generator shall furnish the required certificates and endorsements to
District prior to commencing operation.
9.5 All insurance certificates, endorsements, cancellations, terminations, alterations and
material changes of such insurance shall be issued and submitted to the following:
Truckee Donner Public Utility District
P.O. Box 309
Truckee, CA 96160
10. GOVERNING LAW
10.1 This agreement shall be interpreted, governed and construed under the laws of the
State of California as if executed and to be performed wholly within the State of
California.
C-5
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
11. AMENDMENT,MODIFICATION OR WAIVER
11.1 Any amendments or modifications to this agreement shall be in writing and agreed to
by both parties. The failure of any party at any time or times to require performance
of any provision hereof shall in no manner affect the right at a later time to enforce
the same. No waiver by any party of the breach of any term or covenant contained in
this agreement, whether by conduct or otherwise, shall be deemed to be construed as
a further or continuing waiver of any such breach or a waiver of the breach of any
other term or covenant unless such waiver is in writing.
12. APPENDIX
12.1 This agreement includes the following appendix which is attached and incorporated
by reference: [appropriate Appendix and reference need to be added]
13. NOTICES
13.1 All written notices shall be directed as follows:
Truckee Donner Public Utility District
P.O. Box 309
Truckee, CA 96160
Customer-generator:
Address:
14. TERM OF AGREEMENT
14.1 This agreement shall be in effect when signed by the customer-generator and District
and shall remain in effect thereafter month to month unless terminated by either party
on thirty(30) days' prior written notice in accordance with Section 13.
C-6
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5 - Pre-Demonstration Summary Report
15. SIGNATURE
IN WITNESS WHEREOF, the parties hereto have caused two originals of this agreement to be
executed by their duly authorized representatives.
This agreement is effective as of the last date set forth below.
Customer-generator
By:
Name:
Title:
Date:
Truckee Donner Public Utility District
By:
Name: Peter U. Holzmeister
Title: General Manager
Date:
C-7
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.is—Draft Technology Report
Draft Report
Biomass DG Operating and Economic Characteristics
NOVEMBER 7, 2003
Renewable Energy Research Program
To Make Renewables Part of California's
Affordable and Diverse Public Power System
CONTRACT # 500-01-042
Commission Project Manager: Val Tiangeo
Contractor Project Manager: Fred Weiner—SFPUC
Contractor Program Manager: Ray Dracker -CRS
Subcontractor: Scott Haase-McNeil Technologies
HHWP-042, Del 3.2.3.1, 11-03
'Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.11 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1 a—Draft Technology Report
Table of Contents
1 INTRODUCTION................................................................................................. 1
2 MICRO- AND SMALL-SCALE MODULAR BIOMASS TECHNOLOGY............. 1
2.1 Biomass Cogeneration and Power Applications........................................................1
2.2 Biomass Co-firing in Industrial and Utility Boilers....Error! Bookmark not defined.
2.3 Technology Performance Characteristics—Combustion and Gasification............1
2.4 Biomass Power Generation..........................................................................................5
2.4.1 Biomass Power Technology Overview..................................................................5
2.4.2 Micro-generation....................................................................................................6
2.4.3 Small-Scale Power Generation...............................................................................9
2.5 Emissions from Biomass Combustion and Air Quality Restrictions.....................10
3 SUMMARY........................................................................................................ II
Index of Tables
TABLE 2-1. BIOMASS POWER TECHNOLOGY APPLICATIONS ....................................1
TABLE 2-2. SUMMARY TECHNICAL PERFORMANCE CHARACTERISTICS FOR
BIOMASS DIRECT COMBUSTION POWER PLANTS ................................................3
TABLE 2-3. SUMMARY TECHNICAL PERFORMANCE CHARACTERISTICS FOR
GASIFICATION POWER PLANTS.................................................................................4
TABLE 2-4. MICRO-GENERATION TECHNOLOGY COST AND PERFORMANCE.......8
TABLE 2-5. SMALL-SCALE BIOMASS POWER TECHNOLOGY PERFORMANCE &
COST................................................................................................................................ 10
TABLE 2-7. COMPARISON OF DIFFERENT WOOD-BURNING ALTERNATIVES...... I 1
TABLE 3-1. TECHNOLOGY OPTIONS FOR CALIFORNIA APPLICATIONS ....ERROR!
BOOKMARK NOT DEFINED.
HHWP-042, Del 3.2.3.1, 11-07 i
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
1 Introduction
This Draft Report provides preliminary information on the economic and technical
characteristics of modular biomass energy generation technologies.
The purpose of Task 3.2.3 is to identify and compile information on operating and economic
characteristics for available modular biomass generating equipment used for distributed
generation applications, evaluate the potential for delayed or replaced transmission system
upgrades due to biomass generation, and determine where renewables have a competitive
advantage or significant positive externalities compared to conventional solutions to
California electricity system needs.
This task is divided into two subtasks, 3.2.3.1 Identify Biomass Distributed Generation
Operating and Economic Characteristics and 3.2.3.2 Conduct Scenario Analysis for DG
Applications in System Hot Spots.
The purpose of subtask 3.2.3.1 is to compile data on technical and economic performance
characteristics of modular biomass energy generation technologies for near-term applications.
The focus will be on micro- and small-generation systems, defined as follows:
o Micro-generation:
• size 15—to 50—kW, and
• deployed at load centers with net metering
o Small-generation:
• size I—to 10—MW,
• generating power for sale to wholesale or retail markets,
• either stand-alone plant or in combination with pumped hydro storage
McNeil will identify and finalize the list of relevant equipment suppliers and technologies to
be included in the study, and identify the operating, performance and economic characteristics
to be included in the analysis. McNeil will also develop cost characteristics for candidate
biomass technologies. A preliminary list of the cost information to be collected for renewable
DG technologies includes:
• Capital equipment/technology costs
• O&M Costs
• Interconnection costs
The data and information in this report are preliminary. Additional manufacturers are in the
process of being contacted.
HHWP-042, Del 3.2.3.1, 11-03 1
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
2 Micro- and Small-Scale Modular Biomass Technology
As reported under subtask 3.2.1.1, TDPUD experiences a peak of approximately 30 MW
during the winter season and approximately 20 MW in the summer season. Thus, a micro-
scale DG system, with generation output of 15-kW to 50-kW, would certainly be possible to
site and to operate on the TDPUD system. Based on the typical TDPUD system load, the
upper size limit of a small-scale biopower system should be about 3 MW, unless a portion of
the power output could be sold to another utility.
2.1 Biomass Cogeneration and Power Applications
Biomass power systems convert the energy in wood fuels to electricity. Combined heat and
power (CHP), also known as cogeneration, is a process by which both heat and electrical
power are produced simultaneously, increasing the amount of energy available to a building
or facility by recovering heat.
Biomass power technologies can be used in a wide variety of applications. Table 2-1
summarizes biomass heat and power technology applications.
Table 2-1. Biomass power technology applications
"1 eehuolo es` R Eieatons' Stajis
Small modular biomass (15-500 kW)power
Boiler/steam turbine Commercial, industrial power and cogeneration Commercial
Gasifier/Internal combustion Small commercial power and cogeneration Prototype/pre
engine -commercial
Gasifier/Stirling engine Small commercial ower and co enerat on Prototype
Gasifier/microturbine Small commercial power and cogeneration Design
Gasifier/fuel cell Small commercial power and eo eneration Desi n
Commercial/industrial power(1 MW-5 MW)
Boiler/steam turbine Commercial, industrial power and cogeneration Commercial
Gasifier/Internal combustion Commercial, industrial power and cogeneration Prototype
enine
Gasifier/combustion turbine Commercial, industrial power and co eneration Desi n Demo
2.2 Technology Performance Characteristics— Comhustion and Gasification
Biomass power systems have two main components, an energy conversion system that
converts wood(or other fuel) to useful steam,heat or combustible gases and a prime mover
that uses steam, heat or combustible gas to produce power.
Biomass installations have been created in a considerable range of sizes, from very small
units (5- to 10-kW) to Large facilities (up to 50-MW). Further, biomass power generation
plants vary from simple combustion systems to emerging gasification/pyrolysis units.
Though the common theme among the various technologies is the feedstock, the differing
sizes and market sectors/applications creates challenges for identifying representative
performance characteristics. Furthermore,because many of the technologies, especially, the
smaller unit sizes, are in developmental or demonstration phases, access to meaningful
HHWP-042, Del 3.2.3.1, 11-03 1
Task: 3.2.3 —Distributed Generation Valuation of Project
Sub-task: 3.2.3.1— Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
performance data is limited. This section focuses on technologies that have merit for
development in California over the next decade.
Table 2-2 provides a draft summary of technical performance characteristics for current
biomass combustion systems and Table 2-3 contains data for gasification systems.' In
general the information for combustion systems is more substantiated than for gasification
systems simply because of the widespread commercial use of combustion systems. One
notable absence is emissions data for small-scale gasification systems. While commercial
vendors are developing gasifiers largely because the technology is both more efficient and
produces fewer air emissions relative to combustion, there is very limited operational
experience with the technology, and even fewer reliable emissions studies. Gasification
offers considerable promise and several demonstration units have been constructed with
mixed performance results.
Source: CEC Draft Report, Strategic Valuation Analysis. Data are in the process of being updated.
HHWP-042, Del 3.2.3.1, 11-03 2
Task: 3.2.3 —Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a —Technology Report
Table 2-2. Summary technical performance characteristics for biomass direct
combustion power plants
ME N
Ow
Development Status
Development X
Demonstration X
Commercial X X X
Performance
Rated Full Load Net Capacity kWe 50,000 5,000 50,000
Net Electric Heat Rate Btu/kWh 14,310 24,000 14 280
Electric efficiency % 24% 14% 24%
Overall Capacity Factor % 90% 85% 85%
Operation
Operator Yes Yes Yes
Dis atchable Yes Yes Yes
Load Duty(base, intermediate, peak,
intermittent renewable) B, I B, I B, I
Maintenance
Cold Start Up Time minutes Hours Hours Hours
Annual Maintenance hr/ r 200-300 TBD —400
Time Before Intervention o er, hrs 8,000+ TBD TBD
Tvpical Forced Outa a Rate. % 10% TBD 10%
Siting / Environmental
Power Plant Size
Footprint fe/kW
Air Emissions lb/mWh
CO 3.556 3,8401 0200
NO, 1.500 3.840 L000
so, 0.400 0.758 0.100
UHC TBD TBD 0.100
VOC TBD TBD TBD
PM 1.500 0.346 0.300
Other
Noise db P x feet TBD TBD TBD
Water Consumption(gal/kWh)Wet cooling TBD 1.5 TBD
Water Consumption al/kWh Air/dry Air/dry cooling TBD 0 TBD
Waste Water Production al/kWh TBD TBD
Hazardous Materials TBD TBD
Other hazards TBD TBD
Economics
Facility Life ears 20 20 20
Installed Capital Cost $/kW $2,096 $2,367 $2,459
Fixed Costs,$/kW- r $74.7 $91.0 $82.0
Variable Operating Costs $/kWh W003 $0.003 $0.003
Fuel Cost $/MMBtu $3.00 $3.00 $3.00
Levelized ost o Electricity- onstant Do ars
($/kWh) $0.075 $0.109 $0.082
HHWP-042, Del 3.2.3.1, 11-03 3
Task: 3.2.3 —Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.la—Technology Report
Table 2-3. Summary technical performance characteristics for gasification power plants
zz
�� �,�t, ,- ram, ,r { r f, a sr� "� j � �' , �i��•..
yl r.
Develo ment Status
Development x X X x
Demonstration x x
Commercial
Performance
Rated Full Load Net Capacity kWe 501 1,000 100,000 20,000 100,000
Net Electric Heat Rate HHV Btu/kWh 25,000 12,193 12,507 8,535 9,378
Electric efficiency % 14% 28% 27% 40% 36%
Capacity Factor % 80% 85% 85% 85% 85%
Operation
Operator Yes Yes Yes Yes Yes
Dis atchable No Yes Yes Yes Yes
Load Duty(base, intermediate, peak, I B B B B
Intermittent renewable
Maintenance
Cold Start Up Time minutes 120 Hours 120 Hours
Annual Maintenance hr/ r 150 Unknown 150
Time Before Intervention o er. hrs Unknown Unknown Unknown
Typical Forced Outage Rate % Unknown Unknown Unknown
Siting / Environmental
Power Plant Size
Footprint(ft /kW
Air Emissions WnWh
CO TBD TBD TBD TBD
NO„ TBD TBD TBD TBD
SO, TBD TBD TBD TBD
UHC TBD TBD TBD TBD
VOC TBD TBD TBD TBD
PM10 TBD TBD TBD TBD
Other TBD TBD TBD TBD
Noise db @ x feet TBD TBD TBD TBD
Water Consumption al/kWh TBD TBD TBD TBD
Waste Water Production al/kWh TBD TBD TBD TBD
Hazardous Materials TBD TBD TBD TBD
Other hazards TBD TBD TBD TBD
Economics
Facility Life ears TBD 20 20 20 20
Installed Capital Cost $/kW $1,200 $2,257 $1,070 $2,078
Fixed Costs, $/kW- r $487.4 $84.3 $79.4
Variable Operating Costs $/kWh $0.004 $0.005 $0,004 $0.016
Fuel Cost $/MMBtu $3.00 $3.00 $3.00 $3.00 $3.00
Levelized Cost of Electricity-constant
dollars($/kWh) $0.071 $0.114 $0,068 $0.043 $0.068
HHWP-042, Del 3.2.3.1, I1-03 4
Task: 3.2.3 —Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
2.3 Biomass Power Generation
This section presents a general overview of biomass power generation technology, and then
provides additional detailed information on fuel requirements, performance, and estimated
heat and electricity generation and savings for a range of biomass power applications. For the
purposes of this project, power generation technologies are divided into the following size
categories:
o Micro-generation (15-kW to 50-kW electric generating capacity), and
o Small-scale biomass power generation (I-MW to 10-MW electric capacity).
Micro-generation technologies that use biomass are mostly emerging technologies, but hold
great potential for use in residential and small- to mid-size commercial applications. Mid-
scale biomass power generation technologies can be used for large commercial or industrial
applications and for grid-support for utility transmission and transmission systems. Large-
scale biomass technologies are utility-scale technologies. Due to limitations on the amount of
biomass fuel reliably available, micro- and mid-scale generation technologies are the focus of
this effort.
2.3.1 Biomass Power Technology Overview
Biomass power systems convert the energy in wood fuels to electricity. Cogeneration
describes a process by which both heat and power are produced simultaneously, increasing
the amount of energy available to a building or facility by recovering heat generated as a bi-
product of electricity. Efficiency of electricity generation alone can be as low as 15%, but is
usually in the range of 20 to 40%, using stoker or fluidized bed combustion technology.
Therefore, power plants lose up to 80% of their energy potential through heat loss when
generating electricity. Combined heat and power(CHP) applications can increase the overall
energy efficiency to 70-90 %.2 Existing biomass power plants range in size from 0.5-MW to
75-MW. Most of the operating plants in California are in the 10-20 MW range. Newly
emerging biomass gasification systems are suitable for much smaller application in the 4-75
kW range(micro-generation). There are also generation technologies in the 1-MW to 4-MW
range that have been demonstrated and in some cases built commercially, but these are not
widely available. We are in the process of compiling additional information on the
manufacturers and characteristics/costs of these technologies.
A biomass power or cogeneration system typically consists of a combustor or a gasifier and a
prime mover that uses steam from a boiler or combustible gas from a gasifier to produce heat
or power or both. Producer gas from wood gasifiers can be used to generate power in steam
turbines, reciprocating engines and gas turbines.
The two most common types of technologies to convert wood to steam or combustible gases
include combustors and gasifiers. Commercially available combustion technologies include:
2 Borbely,Anne-Mane. "Combined Heat&Power Energy Reliability and Supply Enhancement."U. S.
Department of Energy Battelle Memorial Institute. 1999.
HHWP-042, Del 3.2.3.1, 11-03 5
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1—Identify Biomass DG Operating and Economic Characteristics
Subject Deliverable 3.2.3.1a —Technology Report
o Pile burners (Dutch oven)
o Stokers
o Fluidized bed combustors
o Inclined fluidized bed combustors
The gasification process is used to convert a heterogeneous biomass feedstock to a consistent
intermediate product(commonly called "producer gas") that can be used for heating,
industrial process applications, electricity generation, and liquid fuels production. The main
combustible components of producer gas are carbon monoxide, methane, and hydrogen. In
addition to these gases, gasification produces nitrogen, oxygen, water vapor, char(carbon),
and ash. The gasification process is similar to combustion, although there are some important
differences. Emissions from gasification systems are typically cleaner and the process can
handle a wider variety of feedstock then combustion systems. Most of the micro-scale power
generation technologies are based on gasification technology. The main types of gasifiers are
updraft, downdraft and fluidized bed. There are still technical hurdles to overcome before
producer gas can be utilized in gas turbines.
The most common devices to convert energy from burners and gasifiers into useful power
(and possibly useable heat) include steam turbines, reciprocating engines and gas turbines.
Steam turbines convert steam from biomass-fired boilers into electricity. Steam-driven
turbine/generators have a conversion efficiency of 17 to 25 percent.] Steam turbines are the
most common form of prime mover used in the biomass industry today, and their sizes range
from 30-kW up to 60-MW. Reciprocating engines can use producer gas from gasifiers in
small modular systems. Industrial gas turbines require high-temperature, high-pressure gas;
the gas rotates the turbine shaft and produces electricity. Many turbines also use a heat
exchanger (or recuperator) so that exhaust heat from the turbine can also be used. These
turbines can be used in combined-cycle or cogeneration applications, enhancing efficiency.
Maintenance costs per unit of power output are among the lowest of all the power-generating
technologies.
The next section discusses micro-generation technology cost, performance and availability.
2.3.2 Micro-generation
Micro-generation technologies, which use gas microturbines or reciprocating engines to
produce heat and electricity, are emerging technologies. Other micro-generation technologies
that use small steam turbines to generate power are commercially available.
Microturbines—Gas microturbines are small turbines evolved from automotive and truck
turbochargers, auxiliary power units for airplanes, and small jet engines and are comprised of
a compressor, combustor, turbine, alternator, recuperator, and generator. Microturbines that
are commercially available are small turbines approximately the size of a refrigerator with a
s Oregon Office of Energy. `Biomass Energy Technologies". *sir; 'wu Enervs*ate.onus-Accessed on
October 31,2001.
HHWP-042, Del 3.2.3.1, I I-03 6
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
capacity of 30 to 75 kW a Microturbines offer a number of potential advantages compared to
other technologies for small-scale power generation. These advantages include a small
number of moving parts, compact size, lightweight, lower emissions, lower electricity costs,
and opportunities to utilize waste fuels. They have the potential to be located on sites with
space limitations for power production.5
While microturbines have not yet been integrated with wood gasification technology in a
commercial manner, Flex Energy of California is designing a system to couple a small-scale
gasifier with a Capstone microturbine.
Reciprocating engines—One prototype system integrates a prototype mobile gasifier with a
modified reciprocating engine that could be used to produce electricity or mechanical power.
The systems can range from 1-kW to approximately 150-kW in electric generating capacity,
with projected commercial availability beginning in the 2004-2005 timeframe. The systems
are portable, and could be towed by a standard pickup. This is the Community Power
System.
Steam turbines - There are a variety of smaller steam turbines in the 90- to 640-kW range
that are commercially available and can be built to order for electricity generation and
cogeneration applications. Delta Dynamics of Boulder, Colorado is developing a 30-kW
steam microturbine. We are compiling additional information on this technology.
Table 2-4 provides detailed information on the cost,performance, and other characteristics of
micro-generation technology, based on manufacturer data and published values. Estimates of
system payback period assume that alI the thermal and electrical output of the system will be
used on-site, thus offsetting retail utility rates. If electricity were sold back to the grid, the
selling price would be most likely lower than the 7 cents/kWh assumed here. The analysis
also does not include the impact of utility stand-by charges that may be imposed by the
utility.
As mentioned before, a site-specific analysis is required prior to consideration of installing a
power generation or cogeneration system to evaluate technical and economic feasibility.
Capstone Microturbine:Opening Up Cogeneration Opportunities,November 28.20001
httr: "ww .buildin een coal rp oeu e>�eap&tane.htaazl. Accessed last on November 28,2001.
5 DOE,Clean Power Technologies, Microturbines hop., w °u e.ren. a , {}v der/cpt micro whatis.hnnt.
HHWP-042, Del 3.2.3.1, 11-03 7
Task: 3.2.3-Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 =Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a-Technology Report
Table 2-4. Micro-generation technology cost and performance
��v� 4it9Be 25�.MFeB!SYRWe-SldrifSdst 3D LL'tieb .�":
..T_..'p�n.`= yyymdaxr 3Uq..+Y�n9ur� 3>k>�g.firhg5rib `mwnt8eg / .- .
.... ..IM41 ♦�v4? s8� !1
Manufacturer Sunpower STM Power STIM power ""one CpC Xylowatl
System Pars mn e w
6pgialional(casfteRiNmcymetasourtq'a Test Test Cmideaeryl capstone: CPC Xyfwvaft
Canceling History 60000
Teclue.111 Status - Test Co Thesch l 6bmisurrel 8evedl de, st lod type CommeraiN
Number In Operates - 10(5999)
Opecombn9 And.,[.me] - 60000 1.5 mIIGon(2) thousands
System size
E1edural Output Capacity kwe 11 25 55 30 15 55
Thermal Output Capacity kWth 2 41 91 85 99 120
reameners
t Depth it 08 - 8,50 4 42 10 -
Width it 0.8 - 2.83 2,33 6 -
raiser it L5 - 5.67 625 7 -
Welghi lb 100 - 3.500 1,052 - -
65 gID in(MT),
Maximum Name Level dBA - 58 Q 7 m 75 @i in(comp) 70 @7m -
F.]use
Input Energy Rate BtuID, 14E.3 266E.3 634E+3 516E+3 484E.3 114E+3
process Temperature 'F 400 ads 400 400 1 650 400
FUN C.,demrfion Rate ohsuiyc 64 135 300 244 119 366
wet lb/hr 24 51 112 91 83 137
Fuel Storage for i nronth operation fl"3 46 974 2,162 1,760 856 21640
Thermal Output Capacity Bill 7,61 139,898 310,505 290,032 338.826 409,457
Efficiency
Overall Heat Rate(fuel inputlerml energy output) BtnNWb 4,030 4,326 4,340 4,465 4,234 4,421
Electrical Heat Rete(fuel lnputuarmanwl energy ouiWl) BWAvWh 12,273 11,007 11,007 17193 32,267 14,067
Total Efficiency % 85 80 80 76 at 77
Electrical Efibust, % 28 31 31 20 11 24
Thermal Efficiency % 57 43 49 56 70 53
Coats
Imalled Cast(total) US$ 42,000 40,000 BQOoo 70.00) 105,Wo 301,988
Unit COeek $/kW, 38,182 1600 1,600 2.333 7,000 5,491
Operating Costs VNIMBte 025 (l 0,25 025 025 025
Brunel Operating Coils $lit 209 4427 9,827 7999 3,901 41,998
Annual Value of Energy Produced - - -
Elabecity, $/Yr 417 9,485 20,867 11,382 3,049 2U67
Thermal Eoes,as Steam Styr 205 3,738 8,296 7749 4.8W 10,9W
Gross Value of Emy,Produced $tyr 622 13,223 2V163 19,131 1898 31,807
Net Value Produced(s, $1, 413 8,795 19,335 1'1,132 3,997 19,808
PMIEmissions
NOx 9/GJ 70 83 31 35 i2 26
Co 15%02 ,/GJ 111 11 114 62 20 ,6
CO g/W 11 ii ,6 122 2 bb
Non Methane HC+VOC g/GJ 9 06 0.6 i9 0
$02 g1GJ 1.0 5.0 so te 2
9 20
input Assumptions(can be modified) Units
Thermal Energy Assumed Value VMMBa 5 5 5 5 5 5
Electric Energy Assumed Value $/kWh 007 0,07 0.07 007 007 007
Annual Operating Hours Tri/yr 5344 5,344 5,344 5.344 2,863 5,344
Biomass Moisture Content %wi 30 30 30 30 25 3)
&omass Energy Content-0,s4HV) Etu4b 8,660 8,660 8,660 8,660 8,660 8,660
Biomass Energy Content-Wet sTHV) Bum, 5,645 5,645 5,645 5,645 5.835 5,645
6lomass Fuel Costs $11MMBtu 2,66 266 2,66 2.66 2.57 2.66
$/dry ton 43 43 43 43 40 43
Sleet but 30 30 30 30 30 30
Notes
(1)STM power web site:hits Hewer stmpowercomliechnOlogy?echnology.asP:734-995-1755
(2)China,than is M furc in test and urieve i it operzGen;-uniuoturcem-m
(3) Ond commencer unit being shipped to Italy for Inslallattoo:personal communication from Leland(Tom)Taykar president of Thermogernes.2002-07 13
(4)Kevin R.Craig and Margaret K.Mann.Cost and Performance Analysis of Three Integrated Biomass Gasification Combined Cycle power Systems, NREL November,1998
(5)A missive value for Net Value Produced indicates that the cost of producing enemy is greater than the value
(6)A use,bbe payback period tedrom es that the energy produced has a regally,hot'aloe
(7)Co9eneas.b from Bansis:A TechMcai Guidebook,P.0.4
HHWP-042, Del 3.2.3.1, 11-03 8
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1—Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
23.3 Small-Scale Power Generation
For the purposes of this project, small-scale generation technologies include steam turbines
and gasifiers, with electrical output capacities between 1 and 10 MW. Steam turbines are
readily available commercially,while gasifiers are still in the demonstration stage. Several
small-scale gasifier technologies can be considered commercial but have only a small
number of systems installed and operating.
Fuel requirements for commercially available small-scale biomass power systems can range
from approximately 9,000 green tons (GT)per year for a 1-MW steam turbine system to over
120,000 GT per year for a 10-MW direct-fired steam turbine system. In the Truckee Donner
district, an appropriate biomass-fueled system size is in the range of 1-MW- The cost-
effectiveness of cogeneration systems is much better than electricity-only systems, so
considerations in siting a mid-scale biomass system should include sites that have a
significant heating or steam load. Installation of a small-scale power or cogeneration system
could be part of a building HVAC retrofit or part of a new construction project.For systems
of this size, it is important to select a system that will permit fuel flexibility in the event that
seasonal fluctuations in biomass fuel supplies create an extended period where forest biomass
supplies are not available.
Table 2-5 provides detailed information on the cost, performance, and other characteristics of
mid-scale power generation technology, based on manufacturer data and published values.
As discussed previously, consideration of an on-site power generation system should include
site-specific cost and feasibility factors. We are in the process of compiling additional
information from other manufacturers of small scale technologies.
HHWP-042, Del 3.2.3.1, 11-03 9
Task: 3.2.3 —Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
Table 2-5. Small-scale Biomass Power Technology Performance& Cost
.. isf�e Y.Ytfita
.... .N7•B+�t.�tb1Y�31Y.
Manuiaelurer Theme. 6EC BEC
Systbn Patan�s
11l+fasu+a0€�VeMcWwybau anwra+? 6X TM1ert'N39att3 huGiugmms DOE'riEEEi. OGE.t�?EC WENflEL;:�' dt)c'.WffiL::
LkereNM iflalpy
Tecfxwl�y$1at15 - fkmn9rtlm RCa%yp¢ R� (gitl'pFJ2l GFryre CgiRclga CpT'eti2l
Number In Opemoon -
Pxrsthg FGstory 11a,M51 -
Ey o
Elec?draM1gRgA CapaSty kW, 1000 1.184 81M 5861 ;263 2,600 t0,000
ThermalOWWt Uaxhf kWtb 2iW 2IW e,t00 5,861 7,034 S4o0 2?OW
Wrtwrlslals - -
�pt?I ft - 36 40 60 60 -
wbh tt - 10 30 70 ro - -
N.,M ft 16 17 30 30
Weigh 10 - -
Mvtimum Nsiea trawl tlBA 93 - 90 90
.I u
nput T&E�To Ra?e d1wM 15 5E+6 ?5 1E+5 a5.2E.6 25.CEW 3J.OE'6 ]OOE.6 2]O.OE6
FISPSS ryH'eture t 4DOM 360360 4W a23 403 4W 4W
use F Cuewun¢tbn Rate .w foNrr J,322 5, i6019 3,2% f3,919 33181 127.792
vet WRrc 2,Ia9 2,036 6919 3268 3919 nU1 47,830
F.gage lor?Pan4epeeealgn ft-3 SZJ]9 138 6382M ?i59?3 62,890 00000 238.821 92i.tb4
TM1em+al grtgA Capaory B¢vbr ],165,49] 9212]82 2]638,34] 20909.060 24000000 18 a25,5C5 J1654.9>4
E y
r He (Nel lnpWuseful a�eyy oulpiH) W 6993 3,6]6 3876 3616 3616 8661 aJtO
Bdnc kS Rae NWwh
1s,4U EB 12Fts 12]W 39 23,]53 23.]53 28.000 21.630
TdafE.aG E 62 88 94 94 39
El ednd ffidercy % +6 2] 2T ?a 13
80 26
Themal ERitimcy % 46 61 61 80 80 26 27
Cen
1.1w WGGGsst(oGi) W z329000 is81338 3.991125 2000,000 2,za1742 622,S00 23 2,3DO
0000
IIM Cos% y 03 1338 oz 1024 ?024 04 20?
ooe<a?k+g cows SrcwA�tu on oas o2s oz4 oza 32s ozs
M wOp ,Cn o 239913 180513 511,540 294,463 953,355 1085$31 g187240
Mewal Vacua d Eaagy Pra W eetl
Ekdritily VY, 191U6 246147 134]613 399,238 479,085 929A24 144"58
Th VAnerg Ea Seam SW 19?,443 6%?a] OW,4 0 a1"042a 1,9144]J50
Goss Valueof Energy Pmhatl ^yYt SIG no933 695,352 2544,515 399.275 4T9035 1940]&3 S52119,
Net Value ammxm(6) yyt J30,93g 514,B38 1$44$14 161,775 125,730 355,2C2 1521,1&1
Ertis
Wo g43i 26 31 31 193 19.3 193 i&3
N'JI ld 15%ar „^w 42 51 51 363 +3 363 Goo
CO 9' 51 fit 62 1J.6 106 ?26 106
Fbn MCNare flC+VM 9f 36,5 a4.a .4 06 06 06 06
502 9G 185 225 V5 24 24 24 24
Mplt AaawegNldK(Canbenb�h/j Untla
TfWrmaE-,,�Vaiue WM 5 5 5 5 5 5 5
Et k Erwvgy 0.55unetl value $+kWh 0071 0.071 o071 9e71 0071 0071 0071
Amual Opwa?Ing Wws nrsryr 5.344 5_.344 534a 5344 5,344 5344 5.34a
Bbrtia55 MYatUre(1uKeeM1 %WI 30 12 12 10 10 30 30
8bmass EnerBY�Mem-PY{HN) &W a560 a6W 8,660 8.6W 8Goo 3.660 8,8
Biomass EneryyfnrrteM-WH(Fhf✓J Ko4b 5.5 7504 7 504 7.665 7 655 5615 SE
Bromacs Fuel Costs bl 266 2W 200 196 196 2% 266
"0tiy fhn 43 34 34 33 33 43 43
5twstbn 30 30 30 30 30 30 30
2.4 Emissions from Biomass Combustion and Air Quality Restrictions
Emissions from a biomass combustion device should be estimated and evaluated on a site-
specific basis to determine whether a particular location is appropriate for developing a
facility. We are doing this as part of other tasks so specifics are not part of this report.
Biomass power generation may provide air quality benefits in rural settings where forest fuels
reduction activities result in open burning of piled biomass. Burning biomass in a controlled
HHWP-042, Del 3.2.3.1, 11-03 10
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 — Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
environment can reduce smoke and particulate matter emissions. The overall impacts of a
biomass combustion device on ambient air quality, taking into account potential benefits
associated with reduction in open burning, may be a factor in permitting a biomass plant.
Table 2-6 shows the emissions associated with pile burning, prescribed burning,wildfire, and
estimates from a Chiptec wood gasifier system. The numbers shown indicate pounds of
pollutant per ton of biomass burned.
Table 2-6. Comparison of Different Wood-burning Alternatives
PM10 NOx j S02 VOC CO
(lbs/green ton)
Pile Burning (1) 19 to 30 j 3.5 0.1 ! 8 to 21 € 154 to 312
Prescribed 24 4.0 N.R.' 13 �224
Burning (2) _
Forest Fire(2) 15 4.0 N.R.' f 21 140
tU4rtc1
k
(1)Patnck Gaffney,California Air Resources Board, 916-332-7303.Available at
w .gisc.t)erkeley.edu/—}scar/agbum/agbumefs.htmt
(2)Enyronment Australia. Emissions Estimation Technique Manual for Aggregated
Emissions from Prescribed Burning and Wildfires,Version 1.0. September 1999,
1.N.R. =not reported
3 Summary
Smaller systems have, in general, high unit cost and low efficiency when compared to larger
systems. Capital costs of systems employing emerging technologies, such as gasification,
microturbines, and Stirling engines are very high in terms of dollars per kW capacity. In
many cases, the value of the thermal energy can equal or exceed the value of the electricity
generated, though the use for the thermal energy is generally limited to the locality of the
biomass equipment. It can not easily or efficiently be transported over long distances. In
many cases, electricity generation using biomass can result in a net reduction in air
emissions.
HHWP-042, Del 3.2.11, H-03 I1
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a —Technology Report
Appendix A. Biomass Technology Vendors
For additional listings, see htVa,Nwuw a.wood s.corn
HHWP-042, Del 3.2.3.1, 1 I-03 A-1
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1 a—Technology Report
�Plr!Peray Name ...... ..... .... @gff 'Taolto61 day
...............
Omar ........
Passat Energi +45 86 65 21 passattd)passatclk www.passart,dir stergade 36 Chun Sonderlyng,DK-8830 biomass boilers
AJB 00 Tittle
Taylor (800)545-2293 tmi(a),mustarroom were'tavlorimmoom Furnaces�hot water heat
Waterstroves
York-Shipley Boiler burner,and accessory
Global Ron Game (800)366-5334 roareeldraesystechoorn wwwursystechoom 693 North Hills Road York PA 17402-2212 manufacturer,
Biomass www.bionessrumbustio
Combustion (508)393-4932 info ilemlormasscomouslionco,u ricam 16 Merriam Road-Princeton,MA 01541 Furnace&boiler systems:150-1200 HP
Systems Robert - Boilers,gasifiers,cogeneration,and waste
Chiptec Bender (800)244-4146 chiptec(ditodether.ne wwwohipteccom 48 Helen Ave.South Burlington VT 05403 reduction systems
Converts Kiln Pat Plass/ (800)949-5456 P.O.Box 341362 Burden TN 38184-1362 Gasifier/boiler systems for steam and heat
Inc. Vernon mass(901)358-4596 production
Babcock& 3535 S.Platte River Drive Unit G-3 Sheridan
Wilcox John Doyle (303)761-3388 hodoyleyb1babcockoont wwwo,aboackoom cc 80110 Boilers and power systems
Boilers and power systems Engineering,
Barlow Group, Gregg (970)226-8557 officeabarlowgrouo.com www,barowgroupoont 2000 Vermont,Ste 200 Fort Collins CO 80525 startup&commissioning,O&M,
Inc. Tomberlin Engineering/PrmuremenUConstruction
Black&Veatch DavisWarren (925)246-8014 www2.bv.com1enerQy_/ee 2300 Clayton Rd Ste 1200,Concord CA 94520 Boiler&power systems:
c/lbionnassr.hfin Engineering/Prmurement(Construction
Detroit Stoker (800) evowdebortstokeroom 1510 East First Street P.O.Box 732 Monroe,MI Biomass boilers
Cormorant, STOKER4 48161
Foster-Wheeler Bill Dillon
(908)713-2500 bill dillonafwcoom www'fwcoom Perryville Corporate Park P.O.Box 4000 Boiler/power plant engineering,design,
I
Inc, x2310 lClinton,New Jersey 08809-4000 construction&finance,O&M
Siemens wwwsiemenswestiroh Boilers&power systems
Westinghouse use.corn
Steam generators and high temperature
Nebraska Boiler (402)434-2006 sales(a),neerlil r,com wenw.neboileroom 6940 Comhusker Highway Lincoln,NE 68507 hot water generators
Messersmith Gailyn (906)466-9010 sales@burnchips.com www.burrichipsot,or 2612 F Road,Bark River,M1,49807 Biomass boiler and furnace conversions
Manufacturing Messersmith
Cleaver-Brooks inf000cleaver-brooks.com wwwoleaver-brooksoom High and low pressure boilers
Industrial 815)562-6400 industrialbiomass(cU,industriglUi www.industrialbioni 8800 South Route 251 Rochelle,IL 61068 Grinders,fuel bins,furnaces,boilers,and
Biomass Inc. omass.com oM_ auxiliary equipment
Energy Products Kent M. (208:17155- epiyeenergyproducts com www.eneratyproduotsoo 4006 Industrial Ave Coeur d'Alene,Idaho USA Fluidized bed boilers,gasifiers,
of Idaho .Pope 1611 in 83815-8928 combustion;materials handling
Hurst Boiler& 877-99HURST
Welding 229-346-3545 tnfoCilhursttboileroorhr www.hursfio00errCQh1 Highway 319 N.,Coolidge,GA 31738 Boilers
Comparry,Inc.
Skinner Engines John Ferrell (814)459-05701aldrinerchAkjap room 337 West 12th Street,PC Box 1149,Erie, Turbines
Pennsylvania 16403
HHWP-042, Del 3.2.3.1, 11-03 A-2
Task: 3.2.3 —Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1 a —Technology Report
... ... ....
pit
Industrial Boiler
&Mechanical (888)853-4714 randy(Wundustrobboiler.corn www.industriallboileccom 3325 N.Hawthorne Street P.O.Box 5100 Boiler installation,repair,and maintenance
Co.,Inc. Chattanooga TIN 37406
Solagen Inc. Francis 33993 Lawrence Road Deer Island,Oregon,
Sharron (503)366-4210 fsharrorkia)solageninc.cord www.solablercriccord 97054 Burners,stokers,rotary dryers
Biomass Energy Dave (205)910-5141 dgamble@bedicusa.com wwvv.becIcusarcom 2240 Rocky Ridge Rd.Birmingham,AL 35216 Turnkey biomass cogeneration systems
Concepts Gamble I
Southern 2240 Rocky Ridge Rd.Birmingham,Alabama steam turbine-generator systems for
Engineering& (800)536-2525 srwwseecausaccorn 35216,800,536.2525 cogeneration applications
Equipment Co.
NESTCO Bob Rivard (508)885-7950 bob(o).nestcol.com sivevoestool.com 64 Main Street,P.O.Box 916,Spencer,MA steam turbine-generator systems for
01562,USA co adoration a fications
Biomass Energy +161 24340 vmwo*ers.biqpond.neLa 56 Gindurra Rd SOMERSBY NSW 2250 Fluidized bed boilers,gasifiers,
Services& besgicbbiontass.com.au
Technology 4911 u/biomass AUSTRALIA combustion:materials handling
External Power
(partners Elaine (740)594-2221 matherfici),sunpower.corn wwwsurpower.corn 182 Mill Street Athens,OH 45701 Combustion J Stirling engine
SunPower,Wood Mather
Mized
Dr.
STM corporation Benjamin (834)995-1755 275 Metty Drive,Ann Arbor,MI 48103 Gasification/Stirling engine
Stiph
FlexEnergy Eden FlexMicroturbine(downdraft
Prabhu (949)380-4899 edanprabhuPcox,net viww.flexerienly.corn 22922 Tiagua,Mission Viejo,CA 92692 gasifier/microturbine)
Community 8420 S.Continental Divide Road Suite#100 Downdraft gasifier,dry gas cleanup,
Power Robb Wait (303)933-3135 rwaltsbriococ,corn WVAN.qocpc.com Littleton,CO 80127 ICE/generator
Corporation
Energy& Darren wwwvoercond.nodak.ed University of North Dakota PO Box 9018 Grand Combustion/heat exchange/steam
Environmental (701)777-5000 mionessiieer urrd.nodak.adu
Schmidt u Forks,ND USA 58202-9018 turbine
Research Center
Agrilectric Karla T
Research Inc. Alexnder (225)922-4662 kalexandeadipowellmoup.corn wwvv.eqnIectric.com P 0.Box 788 Baton Rouge,LA,USA 70821 Combustion/steam turbine
Carbons
Jim Patel (770)956-0601 14501 Circle 75 Parkway Suite E 5300 Atlanta, Updraft gasification,boiler,steam turbine
Cor oration GA,03 9
1
HHWP-042, Del 12.3.1, 11-03 A-3
Task: 3.2.3—Distributed Generation Valuation of Project
Sub-task: 3.2.3.1 —Identify Biomass DG Operating and Economic Characteristics
Subject: Deliverable 3.2.3.1a—Technology Report
Cdhta`cE
Compafry Ftaar@ _::Porsarr .. � Phszna �EtaaiC � W6U dddrsss AdACss&' Technatggy
BG Technologies (410)740-3025 basysfems(o)ba01c com www.botechnolooies.net 10480 Little Patuxent Parkway,Suite 400, Gasification system packages
USA Columbia,MD 21044
Beierle Energy 509-786-1298 P.O.Box 903 Prosser,WA,USA 99350 Portable and stationary gasifiers
Associates Y
Waste to Energy Mike Ling 01787 373007 mike.ungybwaste-to- www.wastetoenergv.co.0 Eystory Borley Green,Sudbury,Suffolk,C010
Ltd enerov.co.uk k 7AH Gasifier modules
XYLOWATT SA
948.86.61 info0,xviowatt.ch www.xylowatt.ch Rte de Vevey 1618 Chatel-St-Denis,Switzerland Gasifier modules(turnkey systems)
48. .6
Thermogenics, thermogenicsOthermooenics. Tom Taylor,President/Thermogenics,Inc.,
Inc. (505)761-5633 Core Mexico
7100-F Second Street NW,Albuquerque,New Gasification system packages
Mexico 87107 USA
Engineers and manufactures a range of
Wellons Ken Kinsie equipment to burn wood-waste fuels for
Incorporated y (503)625 6131 SalesCalWellonsUSA.com wellonsuse.com! PO Box 1030,Sherwood,Oregon 97140-1030 energy production for the forest products
industry;also offers complete engineering
and project management
Cratech Joe Craig cratech(cDonramo.net Pressurized fluidized bed 1.2MWe gasifier
806 327 5220 for cotton trash etc.
Power Energy Gene (303)205-1991 geneg powerenerov.com www.00werenerov.com 6595 W.14th Ave.Suite 203 Lakewood, Converts biomass gasifier output to
Fuels Inc. Jackson Colorado 80214-1998 Ecalene TM
Renewable Oils Int'I Phil Badger (256)740-5634 ebadaerClrenewableoil com www.rgnewableoil.com 3115 Northington Ct.Florence,AL 35360 Converts biomass to fuel oils and
chemicals
Ens n GroupRobert RTP`v Biomass to bio-oils conversion
y Graham (617)266-7600 www.ensvnorouo.com 20 Park Plaza,Suite 434 Boston,MA 02116 process
O namotive James Lames.achesonCalDmaMotive 134 North Van Ness Avenue
y Acheson (323)460-4900 com wnvw.dvnamotive.com Los Angeles,CA 90004 Biomass to bio-oils conversion process
Pellet Fuels Rob Davis (928)537-1647 rdavisMorestenerov.com www.oelletheat.oro 1601 North Kent Street,Suite 1001 Pellet fuel manufacturing technology,
Institute Arlington,VA 22209 markets-industry association
HHWP-042, Del 3.2.3.1, 11-03
A-4
Task 3.2.5— Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5.—Fabrication and Testing of 15 kW Unit
Draft Report
Fabrication and Testing of 15 KW Unit
NOVEMBER 7, 2003
Renewable Energy Research Program
To Make Renewables Part of California's
Affordable and Diverse Public Power System
CONTRACT # 500-01-042
Commission Project Manager: Val Tiangco
Contractor Project Manager: Fred Weiner—SFPUC
Contractor Program Manager: Ray Dracker- CRS
Subcontractor: Scott Haase- McNeil Technologies
HHWP-042, Del 3.2.5, 11-03
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5.— Fabrication and Testing of 15 kW Unit
Table of Contents
1 INTRODUCTION.................................................................................................................3
2 FABRICATION STATUS....................................................................................................3
2.1 Assembly......—..................... ..................... ................ ....... .................---......... 4
2.1.1 Power Generation Module...................................................................................... 4
2.1.2 Gas Production Module .......................................................................................... 5
2.1.3 Feeder and Feeder Drier Module............................................................................ 6
2.2 Testing............................................................................................................................. 7
2.3 Shipping status................................................................................................................ 7
HHWP-042, Del 3.2.5, 11-03 2
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5.— Fabrication and Testing of 15 kW Unit
1 Introduction
This Draft Report provides information about, the status of, and test reports from the fabrication
and testing of the 15 kW BioMax unit. Fabrication of the BioMax 15 unit is now complete. The
unit awaits delivery to the host site.
The goal of Task 3.2.5, Micro Scale Technology Demonstration: Project Development and
Engineering, is to coordinate all aspects of the technology demonstration project. The team will
take the results and information developed under the previous tasks on this project and plan a
suitable demonstration project in the TDPUD service territory. The project wilt seek to document
the costs, energy generation, economic performance, technical performance, emissions and other
criteria associated with running the BioMax technology developed by Community Power
Corporation (CPC) of Littleton, Colorado in a small load center. To accomplish the task goals
McNeil will 1) coordinate with the Recreation Center, CPC, and TDPUD to analyze specific
details of the project(host site needs, utility interconnection agreements, safety, fuel supply,
operating requirements, permits, etc.), 2) conduct engineering design studies and technology
modifications as needed, and 3) make arrangements for system fabrication,procurement,
financing and installation.
In furtherance of these objectives, McNeil shall 1) make all arrangements to locate a host site for
the demonstration project and coordinate between the host site, the utility, and CPC, 2) work
with CPC, the host utility, power marketers and others to ensure that the generator characteristics
of the BioMax system match as closely as possible the high value requirements of the system, 3)
evaluate interconnection requirements, including safety, equipment needs, buy-back rate,
provisions for net metering, and assist the host as necessary in procuring permits, and 4) work
with all parties to determine how the system and technology demonstration project will be
financed, including, as appropriate, the use of California Energy Commission funds. McNeil will
also prepare the final agreements for the technology demonstration signed by all parties, a pre-
demonstration summary report, and a report on the fabrication and testing of the 15 kW BioMax
unit, the biomass technology demonstration project.
2 Fabrication Status
System fabrication, assembly, debug and testing are completed as of October 30`h, 2003. The
system has been operated on wood chip fuel and propane and is generating full power. A picture
of the completed system is shown in Figure 1.
HHWP-042, Del 3.2.5, 11-03 3
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5.—Fabrication and Testing of 15 kW Unit
X £CIF 'i-•
{
{
iv
Figure 1. Completed 15kW SMB System for TDPUD Project
2.1 Assembly
2.1.1 Power Generation Module
Assembly of the power generation module was completed in early September 2003. The scope of
work included removal of stock carburetor from the 35-kVA Generac genset and installation of a
propane injector and vaporizer for controlled fuel delivery. Proportional throttle bodies were
added to regulate producer gas and combustion air, and an 02 sensor and MAP sensor installed
to provide closed loop control feedback on fuel air ratio and load changes. The engine has been
run on propane and all systems are fully operational. See Figure 2.
HHWP-042, Del 3.2.5, 11-03 4
Task 3.2.5—Micro Scale Technology Demonstration. Project Development and
Engineering
Subject: Deliverable 3.2.5. —Fabrication and Testing of 15 kW Unit
r
J
r:
Figure 2 Generac Power Generation Module
2.1.2 Gas Production Module
Assembly of the gas production module was completed on October 17`h, 2003. Assembly
included installation of all fabricated components, installation of pipes and valves, insulation of
all high temperature pipes and valves, installation of control system and wiring harness and
mounting of all sensors. See Figure 3.
HHWP-042, Del 3.2.5, 11-03 5
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5.—Fabrication and Testing of 15 kW Unit
OEM
} t /
ti' {
ht
J'
{
Figure 3 Gas Production Module
2.1.3 Feeder and Feeder Drier Module
The feeder drier was delivered from the fabricator and powder coater on the 24'h of October and
assembly, wiring and testing was completed by October 30te. See Figure 4.
HHWP-042, Del 3.2.5, 11-03 6
Task 3.2.5— Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5.—Fabrication and Testing of 15 kW Unit
fj {
- ..lx..4 x4'•�xf���'t'...
a
�S
Figure 4 Feeder Drier Assembly
2.2 Testing
Following controls and wiring debug, system testing on the gas production module was started
on October 13I`. Six full gas production test runs were conducted on the gas production module
culminating in the final test on October 24`". Engine testing was conducted prior to the gas
production module tests with a separate gas production module. Testing of the feeder drier
system was completed on October 291'. The outcome of system testing is a system that is ready
for integrated field operation. Detailed run reports are available for inspection if desired.
2.3 Shipping status
The system will be held for delivery until ready to be received by McNeil Technologies. We may
elect to continue limited system operation to permit additional burn-in time for system
components and to explore software modifications and improvements that may arise in the
coming months.
HHWP-042, Del 3.2.5, 11-03 7
Task 3.2.5—Micro Scale Technology Demonstration: Project Development and
Engineering
Subject: Deliverable 3.2.5.—Fabrication and Testing of 15 kW Unit
8 m
N
Y
� t
x
x '.
E
x
V
� a
.k `N yg 4p 5
�. ggi
E 9r $ A @ 3w '50 o
HHWP-042, Del 3.2.5, 11-03 8
x C
x y
c ..
N
o ..,... 77d rrn W
Cu itity Gotttroi 4*0ckitst
W v� i 3:ZrbRlfHUItHyYbWN�Ort ..:„$y' � .1.• �
tr Shippra,Checklist
,_, prp {j113 McNeil technolagiestI kW Premmmeraai Prototyao
'" K Bmvme
Gas Producvm Modulei
r
O 4eapAa(9T Jnn Oiaboa
V Gas Produpioo Module r� H
s tern received final teak check urtm to 5 ">A si after 10 min. pi �
:3.. charcoairemoved from flaifror � _
interior vacuumed am cleaned n
O
,.$:...'. m lure disks mvem and wide o[woolds installed 2locetions
wires vrta eM routed O
O TQ
T s 12VDC baturry fully Ma ed
laptop cmn user and cables sN "own"Pownt, w d
electronic Boards removed and paoW for shipment R
major com toproperly bbclu d and braced for trans
O
vianafar ..it for tratrisport � O
arar an inlet blower and valve secured for snuipment �.
E
output pi,es secured for transport
roof ParrOls mounted and severe
doom mounted&segue
purge gas an0 uravx included
all not impes insulated b
K
',{ �: rovers on motor Oontrolkrs sawted '�
19 rearmiation valve pemaneraty mounted
24; not pot i labelled M
i 1'... decals attained
yf, not air vent and ca removed for shipatent ^' ft
new s.Iaw filter installed fD
fi0er Installed O
y, + C
e-r
CI
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-Value
Sites
Sub-task: 3.2.1.2 —Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a.—Characterization and Development Report
Draft
Characterization and Development Report
NOVEMBER 7, 2003
Renewable Energy Research Program
To Make Renewables Part of California's
Affordable and Diverse Public Power System
CONTRACT # 500-01-042
Commission Project Manager: Val Tiangco
Contractor Project Manager: Fred Weiner—SFPUC
Contractor Program Manager: Ray Dracker - CRS
Subcontractor: Scott Haase- McNeil Technologies
HHWP-042, Del 3.2.1.2, 11-03
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2 —Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
Table of Contents
1 Introduction..................................................................................................................2
2 Transmission and Distribution System Characterization ............................................3
3 Desirable Generating Characteristics..........................................................................4
4 Site Characterization....................................................................................................5
4.1 Evaluation of Sites for 15 kW BioMax Facility..................................................5
4.1.1 Truckee Donner Recreation and Park District.............................................5
4.1.2 Forest Service Truckee Ranger Station.......................................................7
4.1.3 Donner Memorial State Park.......................................................................8
4.1.4 Truckee-Tahoe Lumber Company...............................................................8
4.2 Evaluation of sites for one to three MW biomass system ...................................9
5 Permitting ..................................................................................................................10
5.3 Permitting Requirements - General Overview ..................................................10
5.4 Permits Needed for BioMax 15 kW System......................................................13
5.4.1 Permits that May be Needed for 1 to 3 MW System.................................13
Index of Figures
Figure 1. Potential site for BioMax 15 kW demonstration unit..........................................6
Figure 2. Donner Memorial State Park, Facility Headquarters...........................................8
Figure 3. TDPUD Potential Site for 1 to 3 MW Biomass Power Plant...............................9
Index of Tables
Table 1. Permitting Contacts .............................................................................................I I
Index of Appendices
Appendix A. Permitting Requirements For Biomass Systems....................................... A-1
I
Task 3.2.1—Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
1 INTRODUCTION
This Draft Report provides preliminary data, analysis, conclusions, and recommendations
regarding the Characterization and Development of Distribution Generation Site
Evaluations for Truckee Donner Public Utility District(TDPUD).
The goal of Task 3.2.1, Electricity System Analysis and Identification of Potential High-
Value Sites, is to evaluate TDPUD's transmission and distribution (T&D) system to
identify areas where the system faces potential capacity or reliability problems ("hot
spots"), and to compare the performance of conventional solutions to these problems with
those offered by distributed biomass generation. McNeil will examine the available data
and develop locations to test as potential sites for distributed generation. The objectives
for this task are 1) characterize system demand profile and identify T&D hot spots that
are near potential biomass resource sites, 2) compare conventional and biomass resource
alternatives to resolving the local T&D issues, and 3) determine characteristics for
distributed generating (DG)facilities that address T&D hot spots.
The task was further subdivided into Subtask 3.2.1.1 System Data Development and
Analysis Objectives and Subtask 3.2.1.2 Distributed Generation Site Evaluations. This
Draft Report provides the deliverable from Subtask 3.2.1.2 that is 3.2.1.2a—
Characterization and Development Report. The deliverable for Task 3.2.1.1. was
provided previously.
The goal of subtask 3.2.1.2, Distributed Generation Site Evaluations,is to identify sites
with the highest potential distributed generation benefits, considering current and
projected loads and transmission system conditions on both a typical daily and seasonal
basis. Specifically, McNeil shall 1) characterize the transmission and distribution system
in terms of load growth rates, key seasonal variations, and suitability to siting and
interconnection of a modular biomass facility over near-term and 5-year timeframes,
defining system "hot spots;" 2) develop a list of generating characteristics that could be
valuable in any given location(e.g., size of system, dispatchability, peaking
requirements, baseload requirements, cost parameters, ease of operation and
maintenance); 3) integrate the data, after GIS characterization(Task 3.2.2), with other
public benefits such as emissions, biomass resources, fire hazard areas, water, and natural
gas; and 4)prepare a Characterization and Development Report characterizing the most
promising sites and containing a description of operating characteristics and parameters
required for development at each candidate site, implications for product design,
manufacturing, deployment, and operation of technologies.
The activities conducted for this task included discussions and a meeting with TDPUD
personnel, site visits within the TDPUD service territory, receipt and analysis of data
from TDPUD, and the development of preliminary conclusions.
2
Task 3.2.1—Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
2 TRANSMISSION AND DISTRIBUTION SYSTEM CHARACTERIZATION
We characterized the TDPUD system in greater detail in Task 3.2.1.1. A summary is
provided here.
TDPUD, based in Truckee, California, is a small, transmission-dependent utility that
purchases all of its power requirements. It is comprised of four substations (Donner Lake
—60 kV, Tahoe Donner— 60 kV, Truckee—60 kV, and Martis Valley— 120 kV) with a
total of 16 feeder circuits. Each of the substations and the separate metering point
(Glenshire) connect with the Sierra Pacific Power (SPPQ system which is in Nevada.
Because of land considerations, only two of TDPUD's substations offer the potential for
siting distributed generation(DG) —Tahoe Donner and Martis Valley.
TDPUD is characterized as a small utility and experiences a peak of approximately 30
MW during the winter season and approximately 20 MW in the summer season. This
winter-peaking utility experiences a peak load of about 30 MW in the winter(generally at
6 pm the Saturday between Christmas Day and New Year's Day) and a peak load of
about 20 MW in the summer(generally the Saturday of the Fourth of July weekend). The
occurrences of the peak demonstrate that the area's economy and electricity demand are
highly dependent on tourism. There is little air conditioning load and the load shape is
relatively flat in the summer. The system is expecting load growth of approximately 2%
per year from 2003 through 2012.Net retail load is projected to grow from about 126,000
MWh in 2000 to almost 155,000 MWh in 2012.
The system has 11,697 total customers of which 10,424 are residential and 1,273 are
various sizes of commercial. No industrial customers, as the characterization is normally
made, are customers of TDPUD. TDPUD serves its customers from four substations and
sixteen feeder circuits emanate from the substations. Glenshire is a metering point where
TDPUD receives power for Sierra Pacific Power.
No "hot spots"exist on the TDPUD distribution system. Because the system is relatively
small and confined to a limited area, the distribution circuits are somewhat short as
compared to utilities that have both larger loads and bigger service territories. Because of
the size of the system, TDPUD has strong ties between circuits and high levels of
reliability. No distribution system upgrades or substation modifications that TDPUD
plans in the foreseeable future would be avoided by the installation of DG on the system.
The location of TDPUD in close proximity to a biomass resource makes the TDPUD
service territory an attractive location for a DG demonstration project using forest
biomass.
3
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2 —Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
3 DESIRABLE GENERATING CHARACTERISTICS
Desirable generating characteristics for a DG biomass facility do not differ significantly
from the characteristics desired from any conventional or renewable resource by an
operating utility. These characteristics include reliability, dispatchability, fast ramp rate,
quick start capacity, low operation and maintenance requirements, and reasonable costs.
These factors are most applicable to the larger biomass plant that we plan to investigate
as part of this project. The 15 KW unit will not impact the performance of the TDPUD
system in any noticeable manner.
The following DG criteria will be evaluated in greater detail under Task 3.2.4 , Project
Technical Feasibility and Economic Analysis (of the larger biomass plant).
Reliability—the facility should be capable of operating when the utility requires that it
operate or when the host has committed to the utility that it will operate. This means that
the fuel supply is available as needed, the plant does not experience inordinate numbers
of forced outages, forced outages that do occur do not last for unreasonable periods of
time, and that planned outages can be scheduled in conjunction with the host utility.
Dispatchability—the ability of the operator of the plant to control the level of output
from the facility remotely using computer controls. Such remote dispatch includes the
ability to cycle the unit all the way and to ramp it up to meet the daily peak loads.
East ramp rate—the ability of the plant to move from a low load level, or off, to partial
loads and then full load quickly.
Quick start capacity—the ability of a power plant to be turned on and begin operation in
ten minutes. This is not applicable for the biomass plant since it will be operated as a
baseload facility.
Low operation and maintenance requirements—the host desires that a power plant
require maintenance infrequently such that staffing levels, and therefore costs, can be
minimized. This also means a low level of forced outages, no requirement to be turned
off every night, and planned outages for scheduled maintenance that are not overly long.
Reasonable costs—utilities always desire the "least cost' for any generation resource.
This cost incorporates three components—capital, fuel, and operating and maintenance
costs. Power plants with high capital costs generally include low fuel costs therefore
making them economical to be operated to recover their capital costs. Peaking units tend
to have low capital investments but higher operating costs and only run during those
hours that the utilities experience the highest loads.
4
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2 — Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
4 SITE CHARACTERIZATION
This task is broken into two parts; 1) evaluation of potential sites for locating a modular
biomass power demonstration system, and 2) evaluation of potential sites for siting a
stationary one to three MW biomass energy system within the TDPUD service territory.
4.1 Evaluation of Sites for 15kWBioMaxFacility
McNeil staff members, in conjunction with TDPUD staff members, visited possible sites
located at a Truckee Donner Recreation and Park District site and the Truckee Tahoe
Lumber Company to see if they were suitable for conducting a demonstration of a 15 kW
BioMax system. Other sites considered include Donner State Park and the U.S. Forest
Service Truckee Ranger District office.
As this report is being finalized, site selection has focused on the Truckee Donner
Recreation and Park District site for a 15 kW BioMax facility. One primary reason for
focusing on this site is that it is a high-profile community-owned facility located in the
Truckee community, thereby providing high value to TDPUD and the local community
as a demonstration site. One of the primary reasons that TDPUD is supporting the
Biomax demonstration portion of this work is that they want to use the project as market
conditioning for the possible larger biomass generation project. By providing public
education on biomass energy, TDPUD staff believe their customers will be more likely to
support development of a larger unit in TDPUD's service territory.
4.1.1 Truckee Donner Recreation and Park District
The Truckee Donner Recreation and Park District site is located at the Truckee River
Regional Park, located %z mile south of Truckee on Highway 267. The Truckee River
Regional Park consists of ball fields and parks,buildings behind a fence, and a parking
lot. Adequate space exists to accommodate both the building associated with the biomass
microturbine (20 x 50 feet) and the fuel supply itself. A TDPUD transformer is located
next to the potential site (see Figure 1), which is located directly across from a basketball
court that is used as an ice skating rink during the winter. In addition, as there is already
fairly significant traffic associated with usage of the recreation facilities, the increased
truck traffic associated with fuel delivery is not expected to cause any disruptions or
undue burdens on neighboring residences or businesses.
This facility is attractive for TDPUD from a public visibility standpoint and has the
potential to provide economic benefits for the town of Truckee. McNeil personnel
conducted a preliminary analysis of the past three years of electric utility bills for the site.
The BioMax facility is expected to generate 12 kW, 10 hours per day, 6 days per week.
This energy offsets Recreation Center purchases from TDPUD. The total savings in
electricity could total $4,700 per year, at an avoided retail rate of$0.13062/kWh. This is
assuming two weeks of scheduled outages and assuming all other maintenance can be
5
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
handled on Sundays, when the facility is not otherwise being used to generate electricity.
We will conduct a more detailed economic analysis of the project in Task 3.2.4.
E„
Figure 1. Potential site for BioNlax 15 kW demonstration unit
Monthly electricity use by the Truckee River Regional Park ranged from a low of 2,720
kWh to a high of 29,320 kWh per month during the period between August, 2000 and
July, 2003. Electricity use and cost typically spikes between October and May (Figure 2).
35,000
30,000 _...._. .___. _-.___ -- - -----
25,000
20,000
15,000 -------_. ---1
10,000
5,000
O O q N N N N N N M M M
O O O O O O O O O O O O O O O O O O
O O O O O O O O O O O O O O O O O O
N N N N N N N N N N N N N N N N N N
i N O t0 rJ C' fD W (D cD cp cD cD � ih tom- � M O
N N N N N N N N — N N N N N N N N N
W O N N f0 W O N V t0 O N N V (O
Month
-Electricity use(kWh) --Electricity cost($)'
Figure 2. Electricity use and cost at Truckee River Regional Park
6
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
The BioMax 15 kW system will not generate all of the power used by facilities at the
park, but it can significantly reduce the Truckee Donner Recreation& Park District's
electricity purchase requirements. We compared annual electricity usage from 2001, 2002
and 2003 to estimated annual electricity generation and resulting savings from the
BioMax unit. This estimate assumed the BioMax will operate 10 hours per day, 6 days
per week at 80 percent of its full load. This should be considered a maximum potential
savings estimate, since we do not have information on the 24 hour load profile for the
park, showing periods during which more electricity would be generated than that
actually used by the park facilities. During these periods, the park would receive revenue
at 3 cents/kWh from the net metering agreement with TDPUD. Annual electricity use at
the park increased dramatically following 2001. Figure 3 shows estimated annual
electricity generated by the BioMax system is 26 percent of overall usage by the park in
2003. Maximum estimated annual savings is $4,493 per year, also 26% of total costs.
160,000 r
140000 ----- ______ 138,520
I 132,040 ! �
i
120000
100.000
IF
0
80,000 _...... _._.__ _ ..... ..._
i
60,000 ....._.... _________ ___— ......... ..._. !
43,640
40,00020,000
18,008 $17,165
1$5,673 L3$449
BioMai 15 Me
2001 2002 2003 1 maximum potential
savings
r
10 Electricity use tkWhl 43640 138,520 132040 34,560
',®Electncrty cost{$) __$5673 $18,008 $17,165 $4,493
Figure 3. Annual estimated electricity use and cost at park, vs. maximum potential
generation and savings by BioMaxTM unit
4.1.2 Forest Service Truckee Ranger Station
The Truckee Ranger Station headquarters is located at 10342 Highway 89 in Truckee.
This site is not as attractive for siting the biomass microturbine because it might be
relocating, creating additional project costs and uncertainty for the project. It is also not
as high a profile a site in terms of community exposure. The site is a federal facility, and
for this project, TDPUD is interested in doing something that will be seen as offering
more direct benefits to the local community.
7
Task 3.2.1 — Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2 —Distributed Generation Site Evaluations
Subject: Deliverable 3.21.2a -Characterization and Development Report
4.1.3 Donner Memorial State Park
Donner Memorial State Park(Figure 4)is located south of Highway 80 west of
downtown Truckee. This is a public site with high visibility for visitors. The park is
situated in a forested area and is conducting their own hazardous fuels reduction projects
(thinning) in an effort to reduce the risk of wildfires. The building shown in Figure 4 is
the park headquarters. There would be room for the BioMax unit in the foreground.
However, the park is closed in the winter. It is a state-owned facility rather than a Locally
owned facility. As such, the energy savings from the system will not be directly realized
by the community. For these reasons, this park is not as good as a community
demonstration site as the Truckee Regional River Park.
Figure 4. Donner Memorial State Park,Facility Headquarters
4.1.4 Truckee-Tahoe Lumber Company
This facility is currently in operation. Behind the building is a large empty field that
could be a host site for the biomass microturbine. Because this is a privately owned site,
it is not as good a community demonstration as the Truckee Regional River Park.
8
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.21.2a - Characterization and Development Report
4.2 Evaluation of sites for one to three MW biomass system
McNeil personnel, in conjunction with TDPUD personnel, made site visits to the best site
for locating a one to three MW biomass power system, as judged from TDPUD planning
staff. This site is located on one of three adjacent parcels on TDPUD land between an
inactive quarry and a TDPUD water tank facility. The potential site is located on several
(currently) forested acres in an area not easily visible from surrounding areas. The site
has multiple industrial facilities nearby, including a cement mixing facility. The proposed
site is mostly flat, though the land parcel in general has varied topography. It is adjacent
to the Truckee substation. Figure 5 shows the potential plant location.
Lt r.
r
ra, ,
Figure 5. TDPUD Potential Site for 1 to 3 MW Biomass Power Plant
Availability and road access to the site, lack of visibility of the site from recreational and
residential areas, and proximity to an existing substation make this site the best current
candidate from TDPUD's perspective.
9
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
5 PERMITTING
This section describes permitting procedures and requirements in Nevada County for
both the 15 kW BioMax unit and the larger one to three MW unit. Exactly which permits
will be required will depend on the configuration of the system installed and the hardware
chosen. This is easier to determine for the BioMax system since we know most of the
specifics about the system's performance, but is Less clear for a one to three MW unit
since the technology to be used has not been specified. This section, therefore, goes into
some detail about which permit applications will be required for the BioMax system.
Then it provides a more extensive list of the permits that may be needed for the larger
system depending on the system size and technology that would be used.
5.3 Permitting Requirements- General Overview
The three major types of permits that facilities will need to consider deal with air quality,
water quality and building permits. An air tank, boiler and/or propane tank permit may be
required, and local zoning and municipal codes in Truckee will apply to the facility.
There are two major air quality permits that a new facility may need to obtain to comply
with state and federal air quality regulations; an authority to construct permit and an
operating permit. Some systems are exempt from the requirement to obtain these permits.
In California, construction and operating permitting authority are delegated to local and
regional air quality authorities.' In Nevada County, this authority is the Northern Sierra
Air Quality Management District(Northern Sierra AQMD)The rules and regulations for
the Northern Sierra AQMD are available on their website2 and can also be found along
with rules for all other California regional air quality authorities on the Internet at the
California Air Resources Board website.3 Certain major sources of criteria air pollutants
and other sources may need to file for a Title V permit from the U.S. EPA.
Water quality permits may include permits for wastewater discharge into surface water
(including storm water discharge) and sewage/wastewater treatment systems. Federal
National Pollution Discharge Elimination Systems (NPDES) regulations govern
discharge into surface water. NPDES permits are issued by the California Environmental
Protection Agency (Cal/EPA) Water Resources Control Board. Local limits are set by the
Lahontan Regional Water Quality Control Board. The Tahoe Truckee Sanitation Agency
issues industrial wastewater discharge permits into sewer/wastewater treatment systems.
In addition to air and water quality permit requirements, a building permit will be
required. Nevada Count y4 oversees the building permit process. Building plans drawn to
California Air Resources Board. Air Resources Board Permits,Certifications, Exemptions and
Registrations. On-line: httD://www.arb.ca.aovfr)crmits,lr)crTnits.htni
'`Northern Sierra AQMD. On-line:hqg//www.nccn.net/�nsaqni,d/
J California Air Resources Board. On-line:http://www.arb.ca.�,,ov/drdb/nsi/Cur.htm
4 Nevada County. On-line:http://www.mynevadacounty.com
10
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2 —Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
scale, a detailed site plan, detailed foundation plan, floor plan, elevation plan, electricity
layout, square footage of rooms, and two copies of truss and energy calculations. The
building permit checklist provides more information about permit application process. '
The facility may need to obtain an air tank and/or a boiler vessel permit from the
California Department of Industrial Relations. A permit from the is required of all
businesses using (1)pressurized tanks with a volume greater than 1.5 cubic feet and
containing greater than 150 PSI (pounds per square inch) of air; (2) Steam boilers over 15
PSI; or (3)retail stationary propane tanks.6
Table 1 provides contact information relevant to the permitting process.
Table 1. Permitting Contacts
Air Permits
Northern Sierra AQMD
Sam Longmire or Gretchen Berman
Phone: (530)274-9360
200 Litton Dr., Suite 320 P.O. Box 2509
Grass Valle ,CA 95945-2509
California Air Resources Board
Jim Sane
Phone: (916)327-1509
E-mail:jsane(cfarb.ca.
Industrial Storm Water General Permit(NPDES)General Permit No.CAS000001
CaUEPA Lahontan Regional Water Quality Control Board
Harold Singer
Web: http://www swreb ca oov/rwgcb6/
E-mail: HSmger,& b6sswrcb.ca wvv
1 Wastewater Discharge Permits
Tahoe Truckee Sanitation AgencyCraig Woods,General Manager
13720 Joerger Drive
Truckee,CA 96161
Phone: (530) 587-2525
Web: http://wexwarez.com/ttsa/
Nevada County Community Planning Agency,Building Department. Nevada County Building Permit
Application Handbook. On-line: htt ://docs.co.nevada.ca usldse tg/ds py/GetT'ile-9977
6 Cal Department of Industrial Relations Division of Industrial Safety Regulations. Subchapter 1. Unfired
Pressure Vessel Safety Orders.Article 3.On-line: http://www.dir.ca.gov/Title8/sbla3.html;and Subchapter
2. Boiler and Fired Pressure Vessel Safety Orders. http://www.dir.ca.gov/Title8/sub2.htmi
11
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a -Characterization and Development Report
Table 1. Continued
Bnilding Permit Contacts
Nevada County Community Development Agency, Building Department
Clinton McKinley,C.B.O., Director of Building
Phone: (530)265-1583
E-mail: clint.mckinley(a>co nevada ca us
Air Tanks and Boiler Vessel Permits
California Department of Industrial Relations
Pressure Vessel Unit-North
1515 Clay Street Suite 901
Oakland, Ca 94612
Phone: (510)622-3066
Web:http://wwwAir.ca.goviDOSHlnressure html
Municipal Planning and Code Enforcement
Tony Lashbrook,Director
Town of Truckee Planning Division
11570 Donner Pass Road
Truckee,CA 96161
Phone: (530)582-7700
E-mail: tlashbrookCa)tow noftruckee.com
Web: http://www.townoftruckee.coiii/Dlanninu.htnil
i
In addition to these contacts, the CaIGOLD system provides comprehensive information
on business permit requirements in California. This system is on-line at:
http:i/www.cal old.ca.gov/.
Appendix A provides a more detailed discussion of the permitting requirements and
relevant local and federal permit requirements.
12
Task 3.2.1—Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
5.4 Permits Needed for BioMax 15kW System
A building permit from the Nevada County Community Development Agency, Building
Department will be required to install the BioMax 15 kW system.
The Northern Sierra AQMD permitting requirements exempt sources from the need to
obtain authority to construct and operating permits that emit less than one ton per year of
any criteria pollutant specified under national ambient air quality standards (including
ozone, volatile organic compounds, nitrogen dioxide, sulfur dioxide or particulate matter)
or precursor(nonmethane hydrocarbons, an ozone precursor; nitrogen oxides, nitrogen
dioxide precursors; and sulfur oxides, sulfur dioxide precursors).
Community Power Corporation has been working on an ongoing basis with the National
Renewable Energy Laboratory(NREL) Mobile Emissions Testing Laboratory to conduct
emissions testing of the BioMax 15 kW system. A large quantity of data has been
collected and is in the process of being analyzed in order to support calculation of annual
and seasonal emissions data for criteria pollutants. These analyses will support a
determination of whether the BioMax 15 kW system will require an Authority to
Construct Permit and Operating Permit to be obtained from the Northern Sierra AQMD
construction and operating permit requirements, or whether it is exempt from these
requirements. An updated status report on the emissions profile of the system will be
available within a month of this report. It should be emphasized that changes in the
configuration and operating procedures for the system can greatly influence the emissions
patterns of the system. Furthermore, investigation of how these changes can influence
system emissions should be part of ongoing performance testing to optimize the
emissions characteristics of the system. However, it is almost certain that the plant will be
exempt from the authority to construct and operating permits.
The BioMax 15 kW system is small enough to be exempt from the need to apply for a
federal Operating Permit as required by Title V of the Clean Air Act.
There is little or no fluid discharge from the system into either storm water, surface
water, septic or wastewater treatment systems. Therefore, no federal NPDES permit,
Tahoe Truckee Sanitation Agency industrial wastewater discharge is required.
The system may require an air tank and/or boiler permit if a compressed air tank,boiler
or propane tank that meets the size and pressure limits previously described.
5.4.1 Permits that Maybe Needed for Ito 3 MW System
Northern Sierra AQMD and federal air quality permits may be required, as might NPDES
storm water discharge and Tahoe Truckee Sanitation Agency industrial wastewater
discharge permits. Compressed air and boiler permits are also likely to be required. These
permit requirements depend heavily on the size of the system, the combustion technology
used, the system controls, the emissions control system and other site-specific factors.
13
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2 —Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a -Characterization and Development Report
Depending on the site, a zoning variance may be needed to comply with municipal
planning codes.
Determination of whether a larger system will be required to obtain a federal operating
permit through the U.S. EPA depends on whether the source qualifies as a"major source"
or falls within several other classes of emissions sources. Northern Sierra AQMD Rule
522 Part 2.207 refers to federal Clean Air Act rules when it defines a "major source" as:
"a stationary source which has the potential to emit a regulated air pollutant or a
HAP [hazardous air pollutant] in quantities equal to or exceeding the lesser of any
of the following thresholds:
l. 100 tons per year(tpy) of any regulated air pollutant;
2. 50 tpy of volatile organic compounds or oxides of nitrogen for a federal
nonattainment area classified as serious, 25 tpy for an area classified as
severe, or, 10 tpy for an area classified as extreme;
3. 70 tpy of PM 10 (particulate matter of 10 microns or less) for a federal PM 10
nonattainment area classified as serious;
4. 10 tpy of one HAP [hazardous air pollutant] or 25 tpy of two or more HAPs;
or
5. Any lesser quantity threshold promulgated by the U.S. EPA."
Nevada County is not currently considered a non-attainment area for any criteria
pollutant, so the more stringent requirements outlined for nonattainment areas in Rule
522 Part 2.2. used to define a major source do not currently apply.s Since the size of the
unit and technology has not been chosen, the status of the facility as a "major source"
using the regulated air pollutant and HAP standards is not known.
Other sources, according to Northern Sierra AQMD Rule 522 Part 3.1, that may need to
obtain a federal operating permit include sources with an "acid rain unit' and other"non-
major" sources designated by U.S. EPA rules or standards may also require U.S. EPA
federal operating permits. According to Northern Sierra AQMD Rule 522, units with an
"acid rain unit' include fossil-fueled units, which would not apply to a biomass facility.
To date, the U.S. EPA has not designated any other additional "non-major" source
categories that must get a Title V permit, so the proposed facility does not fall within
other U.S. EPA definitions of sources that may require a federal operating permit.9
Cal/ARB. Northern Sierra AQMD Rules and Regulations. Rule 210: Specific Contaminants. On-line:
httpJ/www.arb.ca.gov/DRDB/NSIjCURIITML1R210 HTM. Accessed November 6, 2003.
s U.S. EPA. Greenbook: Currently Designated Nonattainment Areas for All Criteria Pollutants .On-line:
httn:/lwww.era.&ovloar,oagps/greenbk,,ancl html#CALIFORNIA. Accessed November 6,2003.
v U.S. EPA. Who has to apply for a Title V permit'?On-line:
http://www.epa.eov/air/oaqps/permits/whogets.html. Accessed November 6,2003.
14
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
In addition, certain "solid waste incinerator"facilities as defined under Section 129e of
the Clean Air Act may be required to obtain a federal operating permit. The "solid waste
incinerator"definition in Northern Sierra AQMD Rule 522 Part 2.29 excludes certain
small power production and cogeneration units as defined in the Clean Air Act.1° The
Clean Air Act section 129e1 1 defines small power production facilities as those qualifying
under 3(17)(C) of the Federal Power Act (16 U.S.C. 796(17)(C)) and qualifying
cogeneration facilities as those defined in Section 3(1$)(B) of the Federal Power Act(16
U.S.C. 796(18)(B)). These laws defer to Federal Energy Regulatory Commission(FERC)
regulations to define a qualifying small power production or cogeneration facility.12
Under FERC regulations, to qualify as a small power production facility, the facility must
use biomass, waste, solar, wind, or geothermal energy as a primary energy source and
have a power production capacity of not greater than 80 MW. This definition would
exempt the proposed facility from the requirement to obtain a federal operating permit
under Title V if it is not considered a"major source"of emissions. Qualifying
cogeneration facilities meet size, fuel use and efficiency requirements specified under
FERC regulations and that are owned by a person not primarily engaged in the generation
or sale of electric power. FERC defines a qualifying cogeneration facility as being less
than 30 MW in capacity and which meet FERC and PURPA regulations,13 which are
outlined in the U.S. Code of Federal Regulations 18 CFR 202.202.14 Meeting these
regulatory requirements would exempt the proposed facility from the requirement to
obtain a federal operating permit if it is not a"major source"of emissions.
Any source required to obtain a pre-construction permit under the Prevention of
Significant Deterioration (PSD)program or the nonattainment new source review (NSR)
program must also obtain a Title V permit.15 In most cases, these sources will also be
subject to title V because they are major sources. The NSR Program does not apply to a
new facility; rather it governs major modifications to existing facilities. The PSD
program is designed primarily to prevent deterioration of air quality in national parks,
national wilderness areas, national monuments, national seashores, or Class I areas as
10 Northern Sierra AQMD Rules and Regulations Rule 522 Part 202.0. On-line:
http://www.ncen.net/—nsaamd/rule 522 html#PART%202 0. Accessed November 6, 2001
11 Clean Air Act Section 129e.On-line: http://www.e�a.pov/air/c:aa/caa129 txt. Accessed November 6,
2003.
1216 U.S.C_796(18)(B)and 16 U.S.C.796(17)(C).Federal Regulation and Development of Power. and On-
line: ml. Accessed November 6,2003.
13 FERC. Qualifying Facility- How to Obtain Qualifying Status For Your Facility On-line:
httpalwww.ferc.00v/industries/electriclgen-info/dual-fac asp. Accessed November 6,2003.
10.U.S. CFR 292.202.On-line:
http://a257.e.akamaitech.net/7/257/2422/I4mar200lO800,'edocket,access.gpo.gov/cfr 2003/a r9tr/18cfi292
.202.htm Accessed November 6,2003.
U.S.EPA.Who has to apply for a Title V permit?On-line:
http://www.epa.uov/air/oagps/permits/whopets html. Accessed November 6,2003
15
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a -Characterization and Development Report
defined by the Clean Air Act Section 162.16 The Clean Air Act Section 165 defines
permitting requirements and emissions limits that a facility must meet to obtain a pre-
construction permit.17 Any major source located within 100 kilometers of a Class I area
must contact federal land managers to determine the impact of that source on visibility in
the area, and may be subject to pre-construction permit requirements. In the Tahoe area,
Desolation Wilderness is such an area.18 Most of the Truckee vicinity is within 100
kilometers of the Desolation Wilderness. If the proposed facility is a "major source"of
emissions,prior to construction,project engineers should consult with the relevant
federal land managers listed on-line at: http://www.epa.Qov/re,ion09/air/mgpsiflm.html.
The U.S. Forest Service manages the Desolation Wilderness.
is Clean Air Act Section 162.On-line: hrtp://www.epa.eov/airlcaa/caa162.txt. Accessed November 6,2003.
17 Clean Air Act Section 165.On-line: http://www.epa.eovlair/caa/caal65rxt. Accessed November 6,2003.
"U.S. EPA Region 9. California Federal Class 1 Area Map. On-line:
http �icvww spa og v/region09(air�mapslca clSsLhtml. Accessed November 6,2003.
16
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
Appendix A. Permitting Requirements For Biomass Systems
A biomass power system may have to comply with a variety of local, regional and federal
permitting requirements and prohibitions in the Truckee area. These include:
• Northern Sierra AQMD Prohibitions on Emissions,
• Northern Sierra AQMD Authority to Construct Permits,
• Northern Sierra AQMD Operating Permits,
• Northern Sierra AQMD Eligibility for Emissions Offsets,
• Federal Operating Permits as required under the Clean Air Act,
• Federal National Pollution Discharge Elimination System (NPDES) Permits, and
• Nevada County Community Development Agency, Building Department permits.
All Northern Sierra AQMD requirements can be viewed on the Internet at:
http://www.nccn.net/—nsaqmd/rules and regulations.html. These rules also specify
which facilities are required to obtain a federal operating permit under provisions of the
Clean Air Act. Information on Nevada County building permit requirements can be
obtained on the Internet at: http://does.co.nevada.ca.us/dscgi/ds.py/Get/File-9977 and
Nevada County Building Department contact information can be obtained on-line at:
httn://www.inynevadacountv.com/.
The following subsections describe the relevant regulations and permit requirements in
more detail.
Northern Sierra AQMD Prohibitions on Facilities based on Certain Emissions
Certain types of facilities will not be able to be permitted due to Northern Sierra AQMD
prohibitions on air emissions. Northern Sierra AQMD prohibitions on air emissions are:
• Rule 210.A prohibits discharge of sulfur compounds, calculated as sulfur dioxide
(SO2), in excess of 2000 parts per million by volume (0.2%) of exhaust gas
• Rule 210.B prohibits discharge wood-fired boilers and incinerators from
discharging combustion contaminants in excess of 0.2 grains per cubic foot of dry
exhaust gas at standard conditions
• Rule 210.0 excludes from calculation as combustion contaminants particulate
matter emitted from a source or sources in which "exhaust gases from a
combustion unit or process are used to dry, calcine,pyrolyze, sinter or otherwise
thermally condition, exclusive of combusting any process material."
Rule 210.0 applies to processes in which particulate matter from a combustion unit is not
released to the open environment, such as cement kilns.
A-1
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
Northern Sierra AQMD Authority to Construct Permit
Northern Sierra AQMD Regulation 4 governs what types of facilities need to obtain an
authority to construct permit. This rule states that "any person building, altering or
replacing any source of air contaminants shall first obtain an Authority to Construct
Permit from the Air Pollution Control Officer." Exemptions to the rule requiring
emission sources to obtain an authority to construct permit are described in rule 402E.
These include:
"Steam generators, steam superheaters, water boilers, water heaters, and closed
heat transfer systems that have a maximum heat input rate of less than 50,000,000
British Thermal Units (BTU)per hour gross, and are fired exclusively with one of
the following:
1. Natural gas;
2. Liquified petroleum gas;
3. A combination of natural gas and Liquified petroleum gas.
4. Self-propelled mobile construction equipment other than pavement burners.
5. Implements of husbandry used in agricultural operations.
Rule 402.I also states that sources emitting less than 1 ton per year of any criteria
pollutant or precursor which may be specified by the Air Pollution Control Officer are
also exempt from the requirement to obtain an authority to construct permit.
Northern Sierra AQMD Operating Permits
After an Authority to Construct Permit is obtained, a person must obtain a Northern
Sierra AQMD Operating Permit prior to operating equipment that produces air emissions.
The Air Pollution Control Officer may exempt those sources already exempt under
Authority to Construct Permit requirements. As required by the Air Pollution Control
Officer, the owner or operator of any stationary emissions source may need to record the
source and quantity of emissions and other information needed to determine that the
stationary source is in compliance. Northern Sierra AQMD Operating Permits expire one
year after the date of issuance. The Air Pollution Control Officer may renew such permits
following payment of any relevant fees and a determination of compliance with the Rules
and Regulations.
Northern Sierra AQMD Eligibility for Emissions Offsets
Northern Sierra AQMD Rule 411 B states that emissions reductions from a stationary
source may be eligible to develop emissions offsets if they result in the reduction of
emissions from existing stationary and non-stationary sources. Offsets from non-
stationary sources (e.g., open burning):
"shall be certified by the Air Pollution Control Officer through new facility
Permit to Operate conditions, contracts, or other means deemed adequate by the
A-2
Task 3.2.1—Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
Air Pollution Control Officer. Such emission offsets shall take effect no later than
120 days after initial operation of the new facility or modification."
Rule 411 C specifically details specific weights that are assigned to emissions offsets
based on the geographic area affected by the emissions reduction. Rule 411G states that
emissions reductions of one precursor of a particular secondary pollutant may be used to
offset increases of that same precursor, providing that the net emissions increase does not
contribute to an existing violation or create a new violation of any national ambient air
quality standard.
Federal Operating Permits
Northern Sierra AQMD Rule 401 states that some air emissions sources may be required
to obtain a federal operating permit. Specifically, the rule states:
"Major sources subject to Title V of the Clean Air Act of 1990, shall also comply
with the requirements of Rule 522 Title V - Federal Operating Permits. The
applicant for a major source shall apply to the U.S. EPA for applicable federal
requirements pursuant to Title I of the Clean Air Act of 1990, that have not been
delegated to the District."
Rule 522 Part 2.20 defines a"major source" as:
"a stationary source which has the potential to emit a regulated air pollutant or a
HAP [hazardous air pollutant] in quantities equal to or exceeding the lesser of any
of the following thresholds:
I. 100 tons per year(tpy) of any regulated air pollutant;
2. 50 tpy of volatile organic compounds or oxides of nitrogen for a federal
nonattainment area classified as serious, 25 tpy for an area classified as
severe, or, 10 tpy for an area classified as extreme;
3. 70 tpy of PM 10 (particulate matter of 10 microns or less) for a federal PM 10
nonattainment area classified as serious;
4. 10 tpy of one HAP or 25 tpy of two or more HAPs; or
5. Any lesser quantity threshold promulgated by the U.S. EPA."
Rule 522 Part 3.1 clarifies that under Federal law, sources that could be subject to Title V
requirements include major sources and several other varieties of facility, including:
1. A major source;
2. A source with an acid rain unit for which application for an Acid Rain Permit is
required pursuant to Title IV of the CAA;
3. A solid waste incinerator subject to aperformance standard promulgated
pursuant to section I I I or 129 of the CAA;
A-3
Task 3.2.1 —Electricity System Analysis and Identification of Potential High-
Value Sites
Sub-task: 3.2.1.2—Distributed Generation Site Evaluations
Subject: Deliverable 3.2.1.2a - Characterization and Development Report
4. Any other source in a source category designated, pursuant to 40 CFR Part
70.3, by rule of the U.S. EPA ; and
5. Any source that is subject to a standard or other requirement promulgated
pursuant to section I I I or 112 of the CAA,published after July 21, 1992,
designated,pursuant to 40 CFR Part 70.3, by the U.S. EPA at the time the new
standard or requirement is promulgated.
A biomass facility may or may not be considered a major source under the definition in
Rule 522. In the definitions specified in Northern Sierra AQMD Rule 522 Part 2, The
"acid rain unit"definition refers to fossil-fuel fired units, which is not applicable to a
biomass facility. Section 2.29 of Rule 522 states that solid waste incinerators that include
certain small power production, cogeneration or air curtain incinerators are excluded
from this requirement. See htlp://www.nccn.net/—nsaqmd/rule 522.html for more details
on where to obtain more information on which facilities are exempt from these
requirements. More information is needed to determine if other U.S. EPA rules, standards
or requirements specified by the U.S. EPA may apply to a biomass energy facility.
Federal National Pollution Discharge Elimination System (NPDES)permits
General permits apply to categories of water pollution sources for which only general
requirements are needed to protect water quality. This applies to sources that discharge
non-contact cooling water, defrost water,heat pump transfer water, cooling tower
blowdown, and boiler blowdown. These permits are generally issued by the states.
National Pollution Discharge Elimination System (NPDES) permits regulate any point
source discharging into surface waters, unless that discharge is into a sewage system with
valid permits, or the EPA has ruled that no NPDES permit is needed.NPDES permits
generally control for biological oxygen demand (BOD), turbidity, pH, temperature, and
fecal coliform bacteria. The Cal/EPA Water Resources Control Board administers the
NPDES permit system in California and the Lahontan Regional Water Quality Control
Board governs local water discharge limits in the Truckee area.
Nevada County Community Development Agency Building Department Permits
Nevada County19 oversees the building permit process. Building plans drawn to scale, a
detailed site plan, detailed foundation plan, floor plan, elevation plan, electricity layout,
square footage of rooms, and two copies of truss and energy calculations. The building
permit checklist provides detailed information about the information needed to complete
the building permit application process.20
iv Nevada County.On-line:http./fwww mynevadacounty.com
20 Nevada County Community Planning Agency, Building Department. Nevada County Building Permit
Application Handbook. On-line: htro'//dots co nevada ea.us/dsc>7i/ds_pylGetJFile-9977
A-4