Document:

exv10w16

Exhibit 10.16

Confidential Materials omitted and filed separately with the

Securities and Exchange Commission. Asterisks denote omissions.

REVISED FINAL PROPOSAL

DOE Savannah River Site

Biomass Cogeneration Facility and

K and L Area Heating Plants

Submitted by:

Ameresco Federal Solutions

1820 Midpark Road, Suite C

Knoxville, TN  37921

Under DOE Contract No. DE-AM36-02NT41457

May 11, 2009

 

 

DISCLOSURE OF INFORMATION

This proposal includes data that shall not be disclosed outside the Government and shall not
be duplicated, used, or disclosed—in whole or in part—for any purpose other than to evaluate this
proposal. If, however, a contract is awarded to this offeror as a result of—or in connection
with—the submission of this data, the Government shall have the right to duplicate, use, or
disclose the data to the extent provided in the resulting contract. This restriction does not
limit the Government’s right to use information contained in this data if it is obtained from
another source without restriction. The data subject to this restriction are contained on all
pages.

 

 

			
	 	 	 
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TABLE OF CONTENTS

	 	 	 	 	 

	EXECUTIVE SUMMARY
	 	 	1	 
	1.0 ECM 1 DESCRIPTION
	 	 	4	 
	1.1 ECM Summary Schedule DO-4
	 	 	4	 
	1.2 ECM #1: Biomass Cogeneration Facility
	 	 	4	 
	1.2.1 Detailed Description of ECM
	 	 	4	 
	1.2.1.1 ECM Summary
	 	 	4	 
	1.2.1.2 ECM Design Process
	 	 	5	 
	1.2.1.3 ECM 1 Operation
	 	 	17	 
	1.2.2 Location Affected
	 	 	18	 
	1.2.3 ECM 1 Interface with Government Equipment
	 	 	20	 
	1.2.4 Proposed Equipment
	 	 	25	 
	1.2.5 Expected Lifetime
	 	 	25	 
	1.2.6 Physical Changes to Existing Equipment or Facilities
	 	 	25	 
	1.2.7 Savings Proposed
	 	 	25	 
	1.2.7.1 Annual Project Savings Overview
	 	 	25	 
	1.2.7.2 Annual Energy Baseline Consumption & Costs
	 	 	27	 
	1.2.7.3 Annual Energy Savings Calculations
	 	 	30	 
	1.2.7.4 ECM 1 Performance Measurement
	 	 	30	 
	1.2.8 Utility Interruptions
	 	 	34	 
	1.2.9 Agency Support Required
	 	 	34	 
	1.2.10 Potential Environmental Impact
	 	 	34	 
	1.2.11 ECM Property Ownership
	 	 	34	 
	1.2.12 ECM Project Schedule
	 	 	34	 
	1.3 BAMF Project Components
	 	 	35	 
	1.3.1 BAMF Resource
	 	 	35	 
	1.3.1.1 BAMF Supply
	 	 	35	 
	1.3.1.2 BAMF Pricing
	 	 	36	 
	1.3.1.3 BAMF Acquisition
	 	 	36	 
	1.3.2 BAMF Transportation, Metering, & Delivery
	 	 	36	 
	1.3.2.1 BAMF Transportation & Delivery
	 	 	36	 
	1.3.2.2 BAMF Metering
	 	 	36	 
	1.3.3 BAMF End-Use Project
	 	 	37	 
	1.3.3.1 BAMF End-Use Demand
	 	 	37	 
	1.3.3.2 BAMF End-Use Operations & Maintenance
	 	 	37	 
	2.0 ECM 2 DESCRIPTION
	 	 	38	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
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	2.1 ECM Summary Schedule DO-4
	 	 	38	 
	2.2 ECM #2: Biomass Heating Plants for K& L Areas
	 	 	38	 
	2.2.1 Detailed Description of ECM
	 	 	38	 
	2.2.1.1 ECM Summary
	 	 	38	 
	2.2.1.2 ECM Process Description
	 	 	39	 
	2.2.1.3 ECM Operation
	 	 	40	 
	2.2.2 Location Affected
	 	 	41	 
	2.2.3 ECM 2 Interface with Government Equipment
	 	 	42	 
	2.2.4 Proposed Equipment
	 	 	44	 
	2.2.5 Expected Lifetime
	 	 	44	 
	2.2.6 Physical Changes to Existing Equipment or Facilities
	 	 	44	 
	2.2.7 Savings Proposed
	 	 	44	 
	2.2.7.1 Annual Energy Savings
	 	 	46	 
	2.2.7.2 Annual Energy Baseline Consumption & Costs
	 	 	46	 
	2.2.7.3 Annual Heating Plant Performance
	 	 	48	 
	2.2.8 Utility Interruptions
	 	 	49	 
	2.2.9 Agency Support Required
	 	 	49	 
	2.2.10 Potential Environmental Impact
	 	 	49	 
	2.2.11 ECM Property Ownership
	 	 	49	 
	2.2.12 ECM Project Schedule
	 	 	50	 
	3.0 ENVIRONMENTAL IMPACT OVERVIEW
	 	 	51	 
	3.1 Overview of Environmental Benefits
	 	 	51	 
	3.2 Overview of Environmental Permitting & Assessment
	 	 	51	 
	4.0 ECM PERFORMANCE MEASUREMENT
	 	 	56	 
	4.1 Overview of Proposed Annual Savings
	 	 	56	 
	4.2 M&V Plan Executive Summary
	 	 	56	 
	4.3 Whole Project Data / Global Assumptions
	 	 	57	 
	4.3.1 Risk and Responsibility
	 	 	57	 
	4.3.2 Energy, Water, and Operations and Maintenance (O&M) Rate Data
	 	 	57	 
	4.3.3 Schedule & Reporting for Verification Activities
	 	 	58	 
	4.3.4 Status of Utility Company Incentives
	 	 	59	 
	4.4 ECM-Specific M&V Plan and Savings Calculation Methods
	 	 	59	 
	4.4.1 Overview of ECM Specific M&V Plans
	 	 	59	 
	4.4.1.1 ECM 1: Biomass Cogeneration Facility
	 	 	59	 
	4.4.1.2 ECM 2: Biomass Heating Plants for K& L Areas
	 	 	59	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
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	4.4.2 Energy and Water Baseline Development
	 	 	59	 
	4.4.3 Proposed Energy & Water Savings Calculations and Methodology
	 	 	59	 
	4.4.4 Operations and Maintenance Cost Savings
	 	 	59	 
	5.0 MANAGEMENT APPROACH
	 	 	60	 
	5.1 Integrated Management Review Team (IMRT)
	 	 	60	 
	5.2 Ameresco Management Approach
	 	 	61	 
	5.2.1 Ameresco Corporate Management Team
	 	 	63	 
	5.2.2 Program Manager
	 	 	65	 
	5.2.3 Engineering
	 	 	65	 
	5.2.4 Business Operations
	 	 	65	 
	5.2.5 Safety and Risk Management
	 	 	65	 
	5.2.5.1 Site Safety Management
	 	 	65	 
	5.2.6 Construction
	 	 	66	 
	5.2.6.1 Subcontract Management
	 	 	66	 
	5.2.6.2 Construction Management
	 	 	66	 
	5.2.7 Site Operations
	 	 	67	 
	5.2.7.1 Operations and Maintenance Responsibilities
	 	 	67	 
	5.2.7.2 Repair & Replacement Responsibilities
	 	 	71	 
	5.3 ECM Training
	 	 	71	 
	5.4 Risk/Responsibility Matrix
	 	 	72	 
	6.0 PROPOSAL PRICING INFORMATION
	 	 	85	 
	6.1 Interest Rate
	 	 	85	 
	6.2 Finance Procurement Price
	 	 	85	 
	6.3 Sales Tax
	 	 	86	 
	6.4 Property Tax
	 	 	87	 
	6.5 Insurance
	 	 	87	 
	6.6 Payment/Term
	 	 	87	 
	6.7 Cancellation/Termination/Buyout
	 	 	88	 
	6.8 Prepayments/Buydowns
	 	 	89	 
	6.9 Protection of Financier’s Interest
	 	 	89	 
	6.10 Security Interest in ECM Equipment
	 	 	90	 
	6.11 Assignment of Claims
	 	 	90	 
	6.12 Title to and Responsibility for Contractor-Installed Property
	 	 	90	 
	6.13 Construction Milestones
	 	 	91	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
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APPENDICES

Appendices A through E and G are presented in Volume II.

Appendix F is presented in Volume III.

	 	 	 	 	 

	APPENDIX A — GEOTECHNICAL REPORT
	 	 	A-1	 
	APPENDIX B — FLOW DIAGRAMS FOR BIOMASS COGENERATION PLANT
	 	 	B-1	 
	APPENDIX C — EQUIPMENT LIST & MANUFACTURER INFORMATION SHEETS
	 	 	C-1	 
	APPENDIX D— DESIGN STANDARDS MATRIX
	 	 	D-1	 
	APPENDIX E — PROJECT SCHEDULE
	 	 	E-1	 
	APPENDIX F — PRELIMINARY DESIGN DRAWINGS
	 	 	F-1	 
	APPENDIX G — REVIEW COMMENTS
	 	 	G-1	 

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List of Figures

	 	 	 	 	 

	Figure 1.1: Proposed Cogeneration Facility Site Layout
	 	 	7	 
	Figure 1.2: EPI Fluidized Bed Energy System
	 	 	10	 
	Figure 1.3: EPI Fluidized Bed Cell
	 	 	11	 
	Figure 1.4: Cogeneration Facility Site Location
	 	 	19	 
	Figure 1.5: Biomass Cogeneration Facility Steam Interconnection
	 	 	21	 
	Figure 1.6: Biomass Cogeneration Facility River Water Interconnection
	 	 	22	 
	Figure 2.1: K Area Biomass Heating Plant Location
	 	 	42	 
	Figure 2.2: L Area Biomass Heating Plant Location
	 	 	42	 
	Figure 5.1: Integrated Management Review Team
	 	 	61	 
	Figure 5.2: Ameresco’s SRS Biomass Project Team
	 	 	64	 
	Figure 5.3: Proposed Operations Staffing
	 	 	70	 
	 
	 	 	 	 
	List of Tables

	 
	 	 	 	 
	Table ES.1: Project Economic Summary
	 	 	2	 
	Table 1.1: SRS Site Projection Profile — Steam Demand
	 	 	17	 
	Table 1.2: Utility Interconnection Summary
	 	 	20	 
	Table 1.3: ECM 1 Annual Savings Summary
	 	 	26	 
	Table 1.4: O&M Baseline Costs for D-Area Plant
	 	 	27	 
	Table 1.5: Baseline Energy Consumption
	 	 	29	 
	Table 1.6: ECM 1 Post-ECM Implementation Facility Performance
	 	 	32	 
	Table 1.7: Project Milestones
	 	 	34	 
	Table 2.1: Utility Interconnection Summary
	 	 	42	 
	Table 2.2: ECM 2 Annual Savings Summary
	 	 	45	 
	Table 2.3: Baseline Operating and Maintenance Cost for K Area Plant
	 	 	47	 
	Table 2.4: Baseline Annual Energy Consumption for K Area Plant
	 	 	48	 
	Table 2.5: ECM 2 Post ECM Heating Plant Performance
	 	 	49	 
	Table 2.6: ECM 2 Annual Post ECM Non-Fuel Utilities Cost & Consumption
	 	 	49	 
	Table 3.1: Environmental Permits & Documents
	 	 	52	 
	Table 3.2: Annual Emissions Summary for Biomass Cogeneration Facility
	 	 	54	 
	Table 3.3: Annual Emissions Summary for K&L Heating Plants
	 	 	54	 
	Table 4.1: M&V Plan Summary
	 	 	56	 
	Table 4.2: Utility Cost for ECM (Post)
	 	 	57	 
	Table 4.3: NIST Escalation Rates
	 	 	58	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
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LIST OF ABBREVIATIONS & ACRONYMS

	 	 	 

	ACSR

	 	Aluminum Conductor, Steel Reinforced
	AIA

	 	American Institute of Architects
	ASG

	 	Annual Steam Guarantee
	BAMF

	 	Biomass & Alternate Methane Fuel
	BDF

	 	Bio Derived Fuel
	BFB

	 	Bubbling Fluidized Bed
	Btu

	 	British Thermal Unit
	CATEX

	 	Categorical Exclusion
	CO

	 	Carbon Monoxide
	CO2

	 	Carbon dioxide
	CY

	 	Calendar Year
	DA

	 	Deaerator
	DC

	 	Direct Current
	DDC

	 	Direct Digital Control
	DES

	 	Detailed Energy Survey
	DOE

	 	Department of Energy
	EA

	 	Environmental Assessment
	ECM

	 	Energy Conservation Measure
	EPA

	 	Environmental Protection Agency
	EPI

	 	Energy Products of Idaho
	ESPC

	 	Energy Savings Performance Contract
	°F

	 	Degrees Fahrenheit
	FAR

	 	Federal Acquisition Regulation
	FEMP

	 	Federal Energy Management Program
	FONSI

	 	Finding of No Significant Impact
	FY

	 	Fiscal Year
	gpm

	 	Gallons per Minute
	Hp

	 	Horsepower
	ID

	 	Induced Draft
	IMRT

	 	Integrated Management Review Team
	IPMVP

	 	International Performance Measurement & Verification Protocol
	kgal

	 	Kilogallons
	klbs

	 	Kilopounds
	kV

	 	Kilovolts
	KVA

	 	Kilovolt Amperes

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
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	kW

	 	Kilowatt
	kWh

	 	Kilowatt hour
	LEED

	 	Leadership in Energy and Environmental Design
	M & O

	 	Management and Operations
	M & V

	 	Measurement and Verification
	MBtu

	 	Million British Thermal Units (1 x 106)
	MOA

	 	Memorandum of Agreement
	MOU

	 	Memorandum of Understanding
	MVAR

	 	Megavolt Ampere Reactive
	MW

	 	Megawatts
	NEPA

	 	National Environmental Policy Act
	NFPA

	 	National Fire Protection Association
	NIST

	 	National Institute of Standards & Technology
	NOI

	 	Notice of Intent to Award
	NOx

	 	Nitrogen Oxide
	NPDES

	 	National Pollutant Discharge Elimination System
	O & M

	 	Operations and Maintenance
	PA

	 	Public Address
	PM

	 	Particulate Matter
	PMT

	 	Project Management Team
	POIC

	 	Point of Interconnection
	PPEF

	 	Performance Period Escrow Fund
	PPH

	 	Pounds Per Hour
	PRV

	 	Pressure Reducing Valve
	Psig

	 	Pounds per square inch gauge
	PSUP

	 	Power Services Utilization Permit
	PT

	 	Potential Transformer
	PVC

	 	Polyvinyl Chloride
	QC

	 	Quality Control
	QCM

	 	Quality Control Manager
	REC

	 	Renewable Energy Credit
	RO

	 	Reverse Osmosis
	ROW

	 	Right of Way
	SCADA

	 	Supervisory Control and Data Acquisition
	SCDHEC

	 	South Carolina Department of Health & Environmental Control
	SCDOT

	 	South Carolina Department of Transportation
	SCE&G

	 	South Carolina Electric & Gas

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
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Ameresco Federal Solutions 

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	SNCR

	 	Selective Non Catalytic Reduction
	SO2

	 	Sulfur Dioxide
	SRS

	 	Savannah River Site
	SRNS

	 	Savannah River Nuclear Solutions
	SSM

	 	Site Safety Manager
	VAC

	 	Volts Alternating Current
	VFD

	 	Variable Frequency Drive
	VOC

	 	Volatile Organic Compound
	Yr

	 	Year

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	Revised Final Proposal — May 11, 2009

Ameresco Federal Solutions 

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EXECUTIVE SUMMARY

This Revised Final Proposal (Final Proposal) submitted by Ameresco Federal Solutions, Inc.
(Ameresco) is for the implementation of two biomass Energy Conservation Measures (ECMs) at the
Department of Energy’s (DOE) Savannah River Site (SRS), located in South Carolina, approximately 18
miles south of Aiken and 20 miles east of Augusta, Georgia. The ECMs are being proposed under the
authority and terms of the DOE Biomass and Alternate Methane Fuel (BAMF) Energy Savings Performance
Contract number DE-AM36-02-NT41457 as modified by DO RFP # DE-RP09-09SR22572, dated February 26,
2009. This Revised Final Proposal including technical, pricing, and management data shall remain
valid through June 15, 2009.

The proposal consists of two Energy Conservation Measures (ECMs). ECM 1 provides for the turnkey
installation of a new Biomass Cogeneration Facility with a design capacity of 240,000 pounds per
hour (PPH) of steam and 20 megawatts (MW) of electric power. The new facility will replace the
existing
 D Area coal-fired cogeneration plant. ECM 2 includes the turnkey installation of two 10,500 PPH
steam heating facilities; one to be located in the K Area and one to be located in the L Area.
These systems will replace the aging fuel oil-fired packaged boilers currently serving the K and L
Areas of the site.

The existing D Area cogeneration plant produces both steam and electricity that is consumed on
site. The steam is delivered through a large distribution pipeline that runs several miles from
the plant to the end-user facilities. The plant also produces approximately 15 MW of electricity
that is consumed by DOE facilities on site. The 1950s era plant is fueled by coal and in need of
significant modifications to bring the plant into compliance with current environmental
requirements as well as to be a reliable source of energy. The proposed Biomass Cogeneration
Facility, sited near the existing steam interconnection at the intersection of Burma Road and C
Road, will significantly reduce the distance from the plant to the end-user, resulting in improved
operating efficiency. The new facility will have enough capacity to satisfy all of the site’s
steam requirements and a significant portion of the electrical demand which will allow for the D
Area plant to be shut down.

Currently, the existing heating plant in the K Area provides steam for both the K and L Areas.
Steam is delivered from the K Area plant to L Area facilities through a 6”, 2.5 mile pipeline. ECM
2 provides for replacing the K Area plant with two 10,500 PPH boilers — one boiler located in K
Area and one located in L Area — eliminating the need to use the 2.5 mile distribution line. The
existing K Area plant and the steam line will be shut down.

Clean biomass and bio-derived fuels (BDF) will be the primary fuel source for all of the new
boilers. The clean biomass consists of various types of forest residues, and the BDF consists
primarily of scrapped vehicle tires. Fuel deliveries will be received by Ameresco staff at a fuel
handling yard located within the Biomass Cogeneration Facility site at the Burma Road/C Road
location. The fuel handling yard includes a fuel receiving, storage, and processing area that will
serve the Biomass Cogeneration Facility and the K and L Area Heating Plants. Fuel deliveries to
the K and L Area Heating Plants will be made by Ameresco staff on an as-needed basis from the
central fuel yard.

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The use of renewable energy fuel sources provides many positive economic and environmental benefits
to the SRS and the local community, while providing significant energy and cost savings to SRS.
The savings result from fuel switching (coal to biomass), reductions in line losses by locating the
new cogeneration facility and heating plants closer to end-user facilities, and improved
efficiencies from new equipment sized to better match existing load requirements. Key
environmental benefits of the project include:

	 	l	 	 Over 2,000,000 MBtu/yr of thermal renewable energy production and a minimum
generation of 77,000 mWh (264,444 MBtu) of green power.
	 
	 	l	 	 Annual Energy Savings of approximately 500,000 MBtu/yr
	 
	 	l	 	 No-cost Renewable Energy Credits (RECs)
	 
	 	l	 	 Decrease of water intake from the Savannah River by 1,412,000
kgal/yr, supporting water conservation efforts in the regional drought situation.
	 
	 	l	 	 Reduction of 400 tons/yr of Particulate Matter (PM) emissions
	 
	 	l	 	 Reduction of 3,500 tons/yr of Sulfur Dioxide (SO2) emissions
	 
	 	l	 	 Reduction of 100,000 tons/yr of Carbon Dioxide (CO2) emissions
	 
	 	l	 	 Support of the South Carolina Biomass Council Goals

Ameresco proposes to provide a turnkey package of design, permitting, and installation. Ameresco
will also take responsibility for the operation and maintenance of the cogeneration facility and
heating plants throughout the contract term. Table ES.1 below provides an overview of project
economics (as shown on Schedule DO-4) for Performance Period Year 1.

Table ES.1: Project Economic Summary

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	Project	 	Total Energy	 	 	 	 	 	 
	 	 	Implementation	 	Savings	 	O&M Savings	 	Water Savings	 	Total Savings
	Project	 	Cost*	 	(Year 1, 2012)	 	(Year 1, 2012)	 	(Year 1, 2012)	 	(Year 1, 2012)
	DES Cost
	 	 	[**]	 	 	 	N/A	 	 	 	N/A	 	 	 	N/A	 	 	 	N/A	 
	ECM 1: Biomass
Cogeneration
Facility (D Area
Replacement Plant)
	 	 	[**]	 	 	$	21,053,328	 	 	$	12,482,882	 	 	$	(355,013	)	 	$	33,181,197	 
	ECM 2: Biomass
Heating Facilities
for K & L Areas
	 	 	[**]	 	 	$	558,208	 	 	$	638,970	 	 	$	(25,917	)	 	$	1,171,260	 
	Total
	 	$	149,172,566	 	 	$	21,611,535	 	 	$	13,121,852	 	 	$	(380,931	)	 	$	34,352,457	 
	 

 

			
	*	 	The project Implementation Cost excludes the financial procurement costs.

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Following contract award, the detailed design will be completed and construction of the new
facilities will take place. It is expected that thirty months from the date of contract award will
be required to complete the final design and construction of the main Biomass Cogeneration
Facility. However, Ameresco expects that the K and L Area Heating Plants can be constructed within
18 months of contract award. For this reason, Ameresco proposes an early acceptance of ECM 2.

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	Revised Final Proposal — May 11, 2009

Ameresco Federal Solutions 

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Contract DE-AM36-02NT41457

1.0 ECM 1 DESCRIPTION

1.1 ECM Summary Schedule DO-4

Pricing Schedule DO-4 is included in Section 6.0, Proposal Pricing Information.

1.2 ECM #1:Biomass Cogeneration Facility

1.2.1 Detailed Description of ECM

1.2.1.1 ECM Summary

This ECM comprises the design and construction of a Biomass Cogeneration Facility
(cogeneration facility) to be located to the northwest of the main distribution steam
interconnection at the intersection of Burma Road and C Road. The steam produced from the facility
will be exported to the 200 Areas via the existing distribution system; the green power generated
will be exported to the SRS electrical distribution system via a new interconnection at the
existing F Area substation. The scope of work includes the installation of the cogeneration
facility and all equipment, the site work, and the necessary utility interconnections required for
plant operation. There are three additional items included in the scope (design drawings for these
items to be provided following contract award):

	 	1)	 	The procurement and installation of a new skid-mounted river water pump and new pumping
systems controls at the river water pump house, Building 681-3G.
	 
	 	2)	 	Rework of the electrical feeder from the TNX area to the South Carolina Electric and
Gas (SCE&G) utility line at the D Area.
	 
	 	3)	 	Relocation of the existing L Area capacitor bank.

The cogeneration facility will be sized to provide a continuous supply of steam to site end-users
(based on current and future load projections as presented in the SRS Site Projection Profile
provided by the Government) while optimizing the quantity of green power generated. The system is
designed using applicable national codes and standards for power plants and specific site standards
(refer to Section 5.2). Previously, conceptual design drawings were submitted to the site for
review prior to issuance of this final proposal; a draft version of the “issued for pricing”
drawings is included in Volume III of this proposal. Finalized “issued for construction” drawings
will be submitted to the government for concurrence throughout the first year of the construction
period, as major equipment items are ordered and the design drawings are finalized.

This ECM will provide an estimated savings of over $33 million in the first year of operation
through the offset of coal purchases, and reduced O&M from the elimination of the existing D Area
Power Plant and electrical substation. The renewable energy-fueled cogeneration facility will also
provide renewable energy credits (RECs) to SRS at no cost. For purposes of receiving credit for
implementing this renewable energy initiative, the RECs attached to ECM 1 and ECM 2 will belong to
the Government and will not be claimed nor sold by Ameresco.

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In addition to the design and construction, Ameresco will retain responsibility for fuel delivery,
operations, maintenance of the cogeneration facility and site; repair and replacement of the
cogeneration facility equipment; air and effluent outfall emissions compliance for the cogeneration
facility; and monitoring, measurement, and verification (M&V) throughout the contract term. Refer
to Section 5.2.7 for details on Ameresco’s Site Operations.

1.2.1.2 ECM Design Process

The proposed cogeneration facility will provide steam and power to the SRS site. Several
configurations and energy models were analyzed during the Detailed Energy Survey (DES) phase to
determine the final system sizing and system components. The optimal equipment selection and
sizing was selected to balance the current and future thermal needs of the site while maximizing
green power generation. Final selection resulted in a system composed of two (2) biomass bubbling
fluidized bed boilers, each with an output capacity of 120,000 PPH (240,000 PPH plant total) steam
and one (1) condensing steam turbine/generator with an output design capacity of 20 MW.

Superheated steam will be produced in the new combustor/boiler systems at 850 pounds per square
inch gauge (psig) and 825 degrees Fahrenheit (°F), for delivery to the turbine/generator
unit. Steam is extracted at a reduced pressure (385 psig nominal) from the turbine to meet the
demand of the site, as well as for parasitic use. As the primary purpose of the cogeneration
facility is to provide a continuous supply of steam, the amount of steam extracted from the turbine
will vary to meet the site demand. As the extraction rate varies with the site steam demand, the
gross power output from the turbine/generator will also vary. Based on future steam load forecasts
as presented in the SRS Site Projection Profile provided by the Government (Table 1.1 below),
output from the turbine/generator will range from 8 to 20 MW. The net power exported will vary
from 5 to 17 MW as the new cogeneration facility’s in-house (parasitic) loads will range between
2-4 MW. A detailed basis of design is included in the following subsections.

Site

The location of the new cogeneration facility was selected during the initial feasibility study of
the project. The facility will be located approximately 0.5 miles northwest of the intersection of
Burma and C Roads on a 30 acre site. The development on the site will include the following major
areas: 1) the fuel handling yard, 2) the boiler/combustion system, 3) the power plant, 4) the
cooling tower and outfall piping, and 5) the administration building and site parking. The
placement of the cogeneration facility on this site was optimized to minimize fuel handling
conveyor runs, and to ensure critical systems are located near the operator control room. The
layout was also arranged to make use of the natural topography of the land where possible to
minimize disturbance to the environment. The location and layout of the facilities were also
optimized to the extent possible with regard to interfaces with site utilities (described in
Section 1.2.3), a new storm water collection system and outfall, and the new site fire protection
system.

The storm water system is designed to collect storm water from the impervious portions of the site.
These include building run-off, roadway run-off, and equipment run-off. The system will include a
series of

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catch basins to collect the storm water. The site will be graded to direct the storm
water to each of the
 catch basins. The catch basins will be interconnected by 6”, 8”, and 12” piping. A manhole will
be included to provide maintenance access at each change of direction. Ultimately the storm water
will be directed by gravity to a storm water detention pond which is sized to hold the expected
rainfall peaks in the area. The pond will be complete with a liner and slotted spillway to enable
a controlled release of water to the outfall. The system will be installed with a monitoring
system to measure flow, pH, and conductivity. Major components include catch basins, piping,
manholes for maintenance access, lined 165,000 gallon detention pond, monitoring system, and the
24” outfall.

Extensive soil testing was completed on the site to determine the conditions for the soil and
recommended design for structural support of equipment, facilities, and new pavements. The soil
composition is primarily sand with light clay and therefore requires treatment of the site with an
engineered fill prior to foundation work. A copy of the complete soil report is included in
Appendix A of this proposal.

Logistics of site traffic are designed to allow biomass delivery trucks and other facility traffic
to enter the site from Burma Road. The existing gravel portion of Burma Road will be paved up to
the entrance of the site. Delivery trucks will enter the facility from the Burma Road entrance
using a new deceleration lane, and exit the facility via a new one-way exit along the former route
of Old Burma Road (currently an unmaintained dirt pathway between Burma and C Roads). All other
facility traffic will enter into the new parking lot or the on-site access road, and may then exit
back to Burma Road or use the new one-way exit to C Road.

Delivery trucks will traverse the entrance road to the fuel yard, and after fuel delivery will exit
via Old Burma Road, which will be re-cleared and paved up to C Road at the existing 3-way
intersection of C Road and the entry to the F Area. Old Burma Road will be designated and marked
as a one-way thoroughfare in accordance with South Carolina Department of Transportation (SCDOT)
standards, and the traffic signal at the existing 3-way intersection on C Road will be converted to
a new 4-way intersection. This arrangement provides for a safe traffic flow and allows delivery
vehicles to make left-hand turns across traffic only at a signal-controlled intersection. Also
included in the site scope of work is the removal of the curbed median at the existing 3-way
intersection, and the installation of new loop-control vehicle sensor wiring beneath the pavement
at the new 4-way intersection. Figure 1.1 is an illustration of the overall site layout; the
specific areas within the site are further described in the following pages.

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Figure 1.1: Proposed Cogeneration Facility Site Layout

[**]

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Fuel Handling Yard

The fuel handling yard will serve as the delivery point for all fuel supplies for the cogeneration
facility, as well as the two heating plants serving the K and L Areas. Approximately 40-60 trucks
will enter the site daily (at staggered delivery times) at the Burma Road facility entrance. The
entrance to the yard will include truck scales for weigh-in of all fuel sources for tracking
deliveries. Beyond the entrance will be the unloading equipment, fuel storage area, and the fuel
handling and processing equipment.

For fuel handling operations at the cogeneration facility, front-end loaders and augers/conveyors
will be used at various points in the yard to move fuel between stations, through the yard area,
and into the combustion systems. The biomass wood fuel will be unloaded using three (3) automated
hydraulic truck-dumping stations. The truck-dumpers discharge into a reclaim pit, where the fuel
will be lifted to the first transfer conveyor. The fuel is then screened and processed through a
hogger and disc screen onto a second transfer conveyor. The fuel can then be transferred into the
outside storage area or directly into the metering bins of the combustors. Stored fuel will be
stacked in the outside storage after delivery from the transfer conveyor by use of a circular
stacker/reclaimer. In addition to stacking the fuel, the stacker/reclaimer functions as a
reclaimer to transfer the fuel from the storage stack to the fuel metering bins prior to entering
the combustors.

The total available outside storage for clean biomass is approximately 15 acres, allowing for 30
days of continuous operations without replenishing the on-site fuel storage. The scrap vehicle
tires brought to the site will be unloaded and processed in a separate area before being augured
into a separate reclaimer. The separate unloading area and reclaimer allow for better process
control through mixing with the biomass fuel, and also help to quantify BDF usage in meeting the
requirements of the South Carolina Department of Health and Environmental Control (SCDHEC) air
permit with regards to limits on BDF combustion.

Fuel supplies for the K and L Area boilers will be loaded at the cogeneration facility fuel
handling yard and trucked by Ameresco staff to the K and L Area heating plants as needed, since the
heating plants operate only during a limited heating season. One truckload per day is the
estimated maximum usage at both the K and L Area heating plants during the coldest periods.

Proposed Fuel Yard Components include:

	 	l	 	 Two (2) Truck scales
	 
	 	l	 	 Three (3) Hydraulic truck dumps and reclaimers
	 
	 	l	 	 Front end loaders
	 
	 	l	 	 Dump trucks for site use
	 
	 	l	 	 Live bottom trailers for K and L Area
	 
	 	l	 	One (1) Fuel hogger
	 
	 	l	 	One (1) Screener for oversized product
	 
	 	l	 	Two (2) Magnets for metals screening
	 
	 	l	 	One (1) Stacker & Reclaimer
	 
	 	l	 	One (1) Truck Reclaim for Tires

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	 	l	 	One (1) Shredder for tires
	 
	 	l	 	Multiple conveyors for fuel handling
	 
	 	l	 	One (1) Whole Tree Chipper

The final design of the system was developed with primary consideration given to the following:
handling and processing of multiple fuel types; safe and plentiful fuel storage area on site;
minimized maintenance requirements; reduced downtimes; and provision for flexible operation of the
overall systems.

Combustion/Boiler System

The combustion/boiler system includes the components from the fuel feeders to the exhaust stack,
including the boiler auxiliaries. A bubbling fluidized bed (BFB) combustion technology will be
used for this project. BFB technology uses high pressure air to fluidize a 2-3 foot bed of sand
(inert material) in suspension. The fuel source is fed into the system through air spouts and
mixed into the suspended bed. The system operates using 30-40% theoretical combustion air to
reduce bed temperature and minimize nitrogen oxide (NOx) emissions.

BFB technology is preferable for biomass fuels due to its ability to better tolerate various fuel
types, as well as larger variations in both fuel mixture density and moisture content. BFBs have
the advantage of reduced air emissions due to a more stringently controlled temperature in the
combustion process (1400-1600oF). Compared to stoker technology, the bubbling bed
offers lower uncontrolled air emission rates, resulting in a lower investment for downstream air
pollution control system components. BFBs require less maintenance than the stoker boiler,
resulting in less downtime and lower ongoing costs.

[**]. The EPI system is shown in Figure 1.2. The EPI combustor/boiler offers the following
benefits in this size range of BFB equipment:

     [**]

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Figure 1.2: EPI Fluidized Bed Energy System

Two identical BFBs will be installed in the new cogeneration facility. Both boilers will be sized
for a total design input of 372 MBtu/hr (186 MBtu/hr per boiler) and an output of 240 kpph (120
kpph per boiler). The bubbling bed boiler will produce steam at 850 psig, 825°F. Steam
generated will go through a condensing turbine when generating electricity, or through a pressure
reducing valve (PRV) station which will reduce the pressure to 385 psig. Steam required by the
site and for the cogeneration facility
deaerator (DA) tank will be extracted from the turbine at 385 psig. The 385 psig steam will be
distributed to the existing system via the interconnection to the existing steam header located
just across the street from the new cogeneration facility. Additionally, full capacity fuel oil
burners will also be installed in the combustor to serve as a back up fuel source in case the
biomass feeders are down. Refer to Section 1.2.1.3 for details of SRS steam demand.

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Figure 1.3: EPI Fluidized Bed Cell

Fuel will enter into the combustion metering bins from the fuel transfer conveyors. Metered fuel
is discharged through isolation slide gates and into the fuel spreaders. The spreaders distribute
the fuel across the fluidized bed. The fluidized bed cell as shown in Figure 1.3 includes the
equipment to accept, distribute, and mix air, fuel, and limestone in a high temperature thermal
oxidization environment. The system is designed in accordance with National Fire Protection
Association (NFPA) Section 850. Underbed air and overfire air distribution systems are provided to
allow proper air flow for uniform combustion, to provide cooling of tramp material, and to optimize
overall bed temperature.

The EPI system is specifically designed to include a bed recycle system to accommodate wood and
tire derived fuel containing wires. The tire bed system is a fluidizing bed bottom, wire
separation, and screening system designed to handle high concentrations of wire left over from the
thermal oxidization of shredded tires and tramp material. The metal is recovered from the rest of
the tramp material and bed media then discharged to the hopper for recycling.

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Each of the biomass boilers will include a gas handling system, which includes an induced draft
(ID) fan to pull the boiler flue gas through the economizer. The ID fan exhausts into a fabric
filter baghouse and then to an integral exhaust stack.

Pollution Abatement Control

The fluidized bed system provides an environment to optimize destruction of hazardous air
pollutants and volatile organic compounds. Additional pollution abatement control is included in
this system to comply with air emission requirements.

Particulate Matter Control: Particulate in the gas stream is captured in a pulse-jet baghouse
system. The baghouse captures particulate matter from the flue gas and has removal efficiencies of
99.9+%. The flue gas will then exit through a stack adjacent to the ID fan and baghouse located
just outside of the new cogeneration facility.

Nitrogen Oxide Control: The flue gas from the boiler will be treated in the combustion system
using selective non-catalytic reduction (SNCR) technology to reduce nitrogen oxides. Using the
SNCR will reduce NOx rates to 0.12 lb/MBtu. Urea is injected into the furnace typically above the
over-fire air ports, reacting with the oxides to form nitrogen and hydrogen.

Sulfur Dioxide Control: Since tire derived fuel will be used as a fuel source, each biomass boiler
will also have a bed additive system. The bed additive system will introduce limestone into the
fluidized bed cells in order to reduce sulfur dioxide and other acid emissions. Sulfur dioxide
will be controlled to less than 0.2 lb/MBtu in order to comply with air permit conditions.

Each boiler will include an exhaust stack. Each stack will include an aviation lighting system,
and a continuous emissions monitoring system to measure the stack emissions and provide data
reporting. The system will monitor carbon monoxide (CO), oxygen (O2), NOx,
SO2, reagent slip, and opacity. The data is recorded in the facility supervisory
control and data acquisition (SCADA) system.

Ash Handling System

The fuel will primarily consist of clean biomass sources; therefore, the ash content is expected to
be low, less than 1.0-3.0% of the fuel burned. The ash stream consists of a bottom ash stream and
a flyash stream. Bottom ash will be automatically removed from the biomass boiler with mechanical
conveyors and augered into a hopper outside of the building. Fly ash will be collected at multiple
points along the flue gas exhaust train, including boiler hoppers, mechanical dust collector
hoppers, and baghouse. The flyash system will be a mechanical pneumatic system consisting of
rotary air-lock valves, screw conveyors, drag conveyors, and storage container. The ash collection
hoppers will include water nozzles to keep ash wet and minimize dusting into the plant area.

The ash generated from combustion will be delivered to the landfill or taken off site to potential
end-users. Ameresco will be responsible for ash removal, and the cost is included in the
performance period expenses.

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Major Combustion/Boiler System Components:

	 	l	 	Two (2) 120,000 PPH biomass fluidized bed boilers, including fan systems
	 
	 	l	 	Two (2) Baghouses including Penthouse
	 
	 	l	 	Two (2) SNCR systems (Urea Injection)
	 
	 	l	 	 Boiler auxiliaries (boiler feed water pumps, DA tank, chemical treatment, and
instrumentation) 
	 
	 	l	 	 Boiler control SCADA system
	 
	 	l	 	 Two (2) Ash bins
	 
	 	l 	 	Two (2) Ash storage silos
	 
	 	l 	 	 Two (2) Ash conveying systems (for each biomass boiler)
	 
	 	l 	 	Fuel Oil Storage
	 
	 	l	 	Reagent Storage
	 
	 	l 	 	 Limestone Storage

Power Plant

The power plant will house the boiler feedwater system, the water treatment system, the chemical
treatment system, and the steam condensing turbine. The cooling tower and emergency generators
will be located outside to the west of the power plant. The building will be a pre-engineered
two-tiered metal building and 16,000 sq ft in size. Within the power plant there will be a control
room, break room, storage, chemical and sampling area, and the motor control center. The equipment
components are described in the sections below.

Boiler Feedwater System

A feedwater system will pressurize and deliver deaerated boiler feedwater from the DA tanks and the
desuperheater to the boilers. The boiler feed pumps will pull the heated water from the DA tanks.
Since there is no condensate return infrastructure in place, the DA tanks will receive makeup water
from the water treatment system and from the condensate tank. The feedwater will be delivered to
the boiler at 850 psig and 370oF. There are 2 DA tanks for the boilers; one will be
used as a backup.

Components of the primary feedwater system include the following:

	 	l	 	 Three (3) Boiler feed pumps and motors
	 
	 	l 	 	Two (2) DA tanks with instrumentation and trim
	 
	 	l	 	Piping, valves, and controls

Water Treatment System

River water will be used as the source of water for the process water, regeneration water, and for
fire system water. The river water will be filtered through carbon filters and softeners. Process
water will be treated using Reverse Osmosis (RO) technology and then deionized through a mixed bed
system. This system was designed based on samples collected from the Savannah River during the DES
and from water analysis reports for the D-Area plant. The peak make-up requirement to the
cogeneration facility is

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2,200 gallons per minute (gpm); this would occur at the cogeneration
facility’s full capacity and if the water treatment regeneration cycles were occurring at the same
time. Normal flow rate to the water treatment skid will be 600 gpm. Primary components of the
water treatment system include:

	 	l 	 	 Four (4) Carbon Filters
	 
	 	l 	 	Two (2) Water Softeners
	 
	 	l 	 	 Neutralization Tank
	 
	 	l 	 	RO System
	 
	 	l 	 	 Two (2) Deionized Mixed Beds
	 
	 	l 	 	Neutralization Skid
	 
	 	l 	 	Deionized Water Storage Tank

Chemical Feed System

Chemical feed systems are designed for the boilers to provide protection from corrosion, scale
formation, circulating water biofouling, and to provide pH control. Specific internal boiler water
treatment programs will be designed during the implementation phase. Chemical equipment includes
the following:

	 	l 	 	Boilers

	 	  ̈ 	 	Internal Boiler Water Treatment: Chemical feed skid(s) with injection
pumps. The skid will be pre-piped, pre-wired, including necessary components and
accessories for a complete functional system. Feed skid to be used with chemical
totes.

	 	l 	 	Circulating Water System

	 	  ̈ 	 	Common acid chemical feed skid with injection pumps, pre-piped, pre-wired
and including necessary components and accessories for a complete functional system.
Feed skid to be used with chemical totes.
	 
	 	  ̈ 	 	Corrosion control chemical feed skid with injection pumps (dispersant and
corrosion inhibitor), pre-piped, pre-wired and including necessary components and
accessories for a complete functional system. Feed skid to be used with chemical
totes.
	 
	 	  ̈	 	 Biocide chemical feed skid with injection pumps, pre-piped, pre-wired and
including necessary components and accessories for a complete functional system. Feed
skid to be used with chemical totes.

Turbine System

The turbine will be installed in the power plant building. The turbine generator will have a rated
output of 20 MW and generate at 13.8 kilovolts (kV). The turbine will be provided by TGM;
information on the TGM system is included in Appendix C. The TGM turbine is manufactured in
Brazil; however, Ameresco selected it for the SRS project because of its higher efficiency, lower
cost, and shorter delivery time. Ameresco requested and the contracting officer has added the TGM
turbine to the exemption list for Buy American.

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Electrical Generation Equipment:

	 	l	 	 One (1) TGM Steam Condensing Turbine (20 MW), Model TMCE 25000A
	 
	 	l	 	 Electrical switchgears
	 
	 	l	 	 Two (2) fuel oil-fired emergency generators (1.5 MW each)
	 
	 	l	 	 Surface Condenser
	 
	 	l	 	 High Voltage, Medium Voltage Transformers

Cooling System

	 	l	 	 One (1) two-cell Cooling Tower with variable frequency drive (VFD) Fans
	 
	 	l	 	 Cooling Tower pumps
	 
	 	l	 	 Outfall Sampling Station

Administration Area

A 2,200 sq ft building will be constructed to provide office space for cogeneration facility
management staff and to also provide an area to allow visitors to gather for facility tours.

Fire Protection Plan

The Site Fire Protection Plan includes different methods depending on the type of area and the
recommended practice for fire protection. The site will include a stationary pump as well as the
following elements described below.

Biofuel receiving and storage areas

	 	l	 	 NFPA 850, Recommended Practice for Fire Protection for Electric Generating Plants

	 	  ̈	 	 Fire water loop with hydrants and post indicating valves installed in
accordance with NFPA 24 Standard for the Installation of Private Fire Service Mains and
Their Appurtenances

	 	l	 	 International Fire Code

	 	  ̈	 	 Open access for emergency vehicles

Boiler/Turbine/Equipment yard

	 	l	 	 NFPA 850, Recommended Practice for Fire Protection for Electric Generating Plants

	 	  ̈	 	 Fire water loop with hydrants and post indicating valves installed in
accordance with NFPA 24 Standard for the Installation of Private Fire Service Mains and
Their Appurtenances

	 	l	 	 International Fire Code

	 	  ̈ 	 	Open access for emergency vehicles

Turbine Hall

	 	l	 	 NFPA 850, Recommended Practice for Fire Protection for Electric Generating Plants

	 	  ̈	 	 Oil containment/drainage system

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	 	 ̈
 	 	A hose connection
	 
	 	  ̈	 	 Fixed protection system, detection, and alarm system to cover, as minimum,
the Turbine/Generator bearings and oil containment areas.
	 
	 	  ̈	 	 Turbine shut down control per NFPA 850

Administration Area

	 	l 	 	International Building Code and International Fire Code

	 	  ̈	 	 Detection, alarm, and sprinkler system installed in accordance with NFPA
13 Standard for the Installation of Sprinkler Systems and NFPA 72 National Fire Alarm
Code

Lab, Breakroom, and Bathrooms

	 	l	 	 International Building Code and International Fire Code

	 	  ̈	 	 Detection, alarm, and sprinkler system installed in accordance with NFPA
13 Standard for the Installation of Sprinkler Systems and NFPA 72 National Fire Alarm
Code

Control Room and Electrical Rooms

	 	l 	 	NFPA 850, Recommended Practice for Fire Protection for Electric Generating Plants

	 	  ̈	 	 Detection and alarm system installed in accordance with NFPA 72 National
Fire Alarm Code

	 	o
	 	 Detection, alarm, and fixed protection under raised floors.

	 	v
	 	Fixed protection — Dry Chemical, NFPA 17

Biofuel Conveyors and Transfer Towers

	 	l	 	 NFPA 850, Recommended Practice for Fire Protection for Electric Generating Plants

	 	  ̈ 	 	Protection, detection, and alarm systems are not required but are a good practice

	 	o
	 	Dry type deluge system install in accordance with NFPA 13 Standard for
the Installation of Sprinkler Systems

	 	  ̈	 	 Detection and alarm system installed in accordance with NFPA 72 National
Fire Alarm Code

	 	  ̈	 	Conveyor controls to be interlocked per NFPA 850

Cooling Tower

	 	l 	 	NFPA 850, Recommended Practice for Fire Protection for Electric Generating Plants

	 	  ̈	 	 Hydrant installed in accordance with NFPA 24 Standard for the Installation
of Private Fire Service Mains and Their Appurtenances
	 
	 	  ̈ 	 	Cooling Tower design and constructed in accordance with NFPA 214, Standard
on Water-Cooling Towers

Fuel Oil Storage Tank

	 	l	 	 NFPA 30: Flammable and Combustible Liquids Code

	 	  ̈ 	 	Separation in accordance with NFPA 30
	 
	 	  ̈	 	 100% containment in accordance with NFPA 30

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	 	  ̈	 	 Design and construction in accordance with NFPA 30
	 
	 	  ̈	 	 Hydrant installed in accordance with NFPA 24 Standard for the Installation
of Private Fire Service Mains and Their Appurtenances

1.2.1.3 ECM 1 Operation

ECM 1 will be operated continuously to produce steam and power for SRS, with the primary
mission of meeting the Annual Steam Guarantee (ASG). The ASG is the total amount of steam output
from the biomass boilers as defined in Section 1.2.7.4. During normal operation, steam produced
from the boilers will flow through the condensing steam turbine. Steam required for the
cogeneration facility auxiliaries and the export steam required by the site will be extracted from
the turbine. The balance of steam will continue through the turbine to generate additional green
power. As required by SRS, the cogeneration
facility will be operated to provide steam at 350 psia through the existing Government-owned
distribution system to the users in the F and H Areas.

Scheduled outages will not exceed one per year and only one boiler will be taken down at a time for
planned maintenance. In the unlikely event that both boilers are inoperable, Ameresco has made
provisions and connections for bringing temporary boilers to the site to ensure the supply of
steam.

Projected steam demands of the site are based on information provided in the SRS Site Projection
Profile provided by Government personnel. The projections upon which the cogeneration facility
performance model is based was provided by government personnel in the SRS Site Projection Profile
and shows that annual steam loads will differ for the next 20 years as shown in Table 1.1. Due to
these changes in operation and the anticipated variation in weather from year to year, it is
proposed that the new cogeneration facility will be operated to produce a fixed quantity of steam
each year, the ASG. As the demand for exported steam decreases, the amount of green power
generation will increase, up to the ASG.

Table 1.1: SRS Site Projection Profile — Steam Demand

	 	 	 	 	 	 	 
	 	 	Winter peak	 	Winter average	 	Summer average
	Year	 	[kpph]	 	[kpph]	 	[kpph]
	2009
	 	[**]
	 	[**]
	 	[**]
	2010
	 	[**]
	 	[**]
	 	[**]
	2011
	 	[**]
	 	[**]
	 	[**]
	2012
	 	[**]
	 	[**]
	 	[**]
	2013
	 	[**]
	 	[**]
	 	[**]
	2014
	 	[**]
	 	[**]
	 	[**]
	2015
	 	[**]
	 	[**]
	 	[**]
	2016
	 	[**]
	 	[**]
	 	[**]
	2017
	 	[**]
	 	[**]
	 	[**]
	2018
	 	[**]
	 	[**]
	 	[**]
	2019
	 	[**]
	 	[**]
	 	[**]
	2020
	 	[**]
	 	[**]
	 	[**]

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 18
	 	Contract DE-AM36-02NT41457

Table 1.1: SRS Site Projection Profile — Steam Demand

	 	 	 	 	 	 	 
	 	 	Winter peak	 	Winter average	 	Summer average
	Year	 	[kpph]	 	[kpph]	 	[kpph]
	2021
	 	[**]
	 	[**]
	 	[**]
	2022
	 	[**]
	 	[**]
	 	[**]
	2023
	 	[**]
	 	[**]
	 	[**]
	2024
	 	[**]
	 	[**]
	 	[**]
	2025
	 	[**]
	 	[**]
	 	[**]
	2026
	 	[**]
	 	[**]
	 	[**]
	2027
	 	[**]
	 	[**]
	 	[**]
	2028
	 	[**]
	 	[**]
	 	[**]
	2029
	 	[**]
	 	[**]
	 	[**]
	2030
	 	[**]
	 	[**]
	 	[**]
	2031
	 	[**]
	 	[**]
	 	[**]

Ameresco staff will be responsible for operating and maintaining the cogeneration facility
throughout the contract term as detailed in Section 5.2.7.1, and the cogeneration facility will be
continuously manned by
Ameresco staff as described in Section 5.2.7. However, this Final Proposal excludes any operation
and maintenance obligations on the part of Ameresco except as detailed in Section 5.2.7.1

1.2.2 Location Affected

During the Initial Proposal kickoff meeting, the Government presented three sites as potential
locations for the new cogeneration facility. The selected site is shown in Figure 1.4 below and
was agreed upon by SRS, the M&O Contractor, and Ameresco based on an evaluation of many factors,
including distance to existing utility connections, available acreage, accessibility, security
concerns, and environmental impacts. A site-use permit was obtained and is currently being amended
to include the electrical feeder to the F Area, the river water piping tie-in from the C Area, the
process water outfall to Upper Three Runs Creek, and improvements to the Old Burma Road/C Road
intersection.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 19
	 	Contract DE-AM36-02NT41457

Figure 1.4: Cogeneration Facility Site Location

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	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 20
	 	Contract DE-AM36-02NT41457

1.2.3 ECM 1 Interface with Government Equipment

Title to all Ameresco installed equipment will transfer to the Government at the time of
Government acceptance of an ECM. Title to the biomass fuel will transfer to and vest in the
Government simultaneously with Ameresco’s receipt of the biomass at the fuel handling yard. For the
sake of clarity, ECM 1 will interface with existing Government equipment at the utility
interconnections as described in this section. The installation of utility interconnections
required for the new cogeneration facility are included in the project implementation cost and the
installation will be Ameresco’s responsibility; however, the SRS M&O Contractor will retain O&M
responsibility including repair and replacement for the utility interconnections and utility
distribution systems. Table 1.2 provides a summary of the utility interface and the scope of O&M
responsibility for the utility systems. Ameresco and the SRS M&O Contractor will enter into an
agreement that will provide the cogeneration facility with utility services to include river water,
sanitary sewer service, backup electrical power, and domestic water service. A Power Services
Utilization Permit (PSUP) form will be completed by Ameresco prior to construction of utility
interconnections. Utility meters will be installed to measure usage. It is proposed the
Government will incur the cost for the cogeneration facility’s non fuel utilities. These Post-ECM
Implementation Costs have been factored into the annual savings. The annual consumption and costs
of the utilities are shown in Table 1.6, and the unit cost used for each utility is shown in Table
4.2. Refer to Section 5.2.7.1 for operation and maintenance responsibility.

Infrastructure services (site facility operations and maintenance) are primarily the responsibility
of the Site M&O Contractor. M&O Contractor personnel operate and maintain the SRS utility systems
and manage site environmental programs. On site DOE personnel are charged with oversight of M&O
Contractor operations although M&O Contractor personnel often render project or program decisions
for the Government. Therefore, for purposes of this proposal, the use of the term “Government” is
applicable
to DOE and M&O Contractor. For example, the term “Government caused delays” includes any delays
caused by government and/or M&O Contractor personnel. Although the M&O Contractor makes
operational decisions for the systems they operate and programs they manage, only DOE personnel,
i.e. Contracting Officer and Contracting Officer’s Representative (COR) will provide project and
program decisions affecting work performed by Ameresco or Ameresco subcontractor personnel
resulting from this proposal.

Table 1.2: Utility Interconnection Summary

	 	 	 	 	 
	Utility	 	Interconnection	 	O&M Responsibility
	Steam

	 	New 12”, 240 kpph
line from plant to
existing 24” across
Burma Road
	 	Ameresco: To the point of the new valve
located in a new 12” line near the point of
interconnection (POIC) with the existing steam
line. SRS: Upstream of the new valve.
	 
	 	 	 	 
	Domestic Water

	 	30 gpm, new 2” line
from plant to
header located
outside existing
water treatment
plant
	 	Ameresco: To the new utility valve outside of
power plant. SRS: Downstream of the tie-in
to the new valve.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 21
	 	Contract DE-AM36-02NT41457

Table 1.2: Utility Interconnection Summary

	 	 	 	 	 
	Utility	 	Interconnection	 	O&M Responsibility
	River Water

	 	New 12”,2200 gpm
line from valve
house near C-Area
to new biomass
plant
	 	Ameresco: Downstream of the interconnection
valve. SRS: From existing pump station up to
interconnection valve at cogeneration
facility.
	 
	 	 	 	 
	Outfall

	 	1200 gpm + storm
water runoff, new
24” line to Upper
Three Runs Creek
	 	Ameresco: To conduct all testing of the
effluent; responsible for maintaining
compliance of this discharge.
	 
	 	 	 	 
	Sanitary Sewer

	 	New 4” line & new
lift station, 20
gpm to upside of
the existing Lift
Station
	 	Ameresco: To the new valve located in the new
line outside of power plant. 

SRS: Downstream of the new utility valve.
	 
	 	 	 	 
	Electrical

	 	New 13.8 kV line
to/from F Area
substation
	 	SRS: From outside of new cogeneration facility
	 
	 	 	 	 
	Fire Water System

	 	Tapped off the new
river water header,
prior to cooling
tower
	 	Ameresco: Responsible for fire water system
	 
	 	 	 	 
	Telephone
Line/Public Address
(PA) System

	 	Verizon New Line
	 	Verizon/Ameresco
	 
	 	 	 	 
	Data Line

	 	Verizon New Line
	 	Verizon/Ameresco

Steam Distribution System

Steam produced from the boiler at 850 psig and 825°F will flow through the turbine, or
through a pressure reducing valve (PRV) and desuperheater if the turbine is not operating. From
the turbine or PRV, the steam will be exported to the SRS distribution system, with a small
percentage going to the cogeneration facility DA tanks. Flash steam from the continuous blowdown
flash tank is supplied to a low pressure header to supplement the steam requirements of the DA.

The steam exported to the distribution system will be delivered at 350 psig 450oF. A
new 12” carbon steel pipe will be routed above-ground from the cogeneration facility (exiting from
the turbine or PRV station) to the existing steam line located across Burma Road. A steam meter
will be installed in the line to measure steam exported from the cogeneration facility, as well as
a steam meter on the flow exiting the boilers to measure the total amount of steam produced. The
new cogeneration facility export connection is approximately 3 miles closer to the F and H Areas
than the existing D Area plant, providing increased distribution system efficiency from decreased
line losses. The approximate point of interconnection is shown in the photograph below:

Figure 1.5: Biomass Cogeneration Facility Steam Interconnection

[**]

Domestic Water

A 2” domestic water line will be installed to serve plant potable water needs such as bathrooms,
utility sinks, showers, and eye wash stations. The new water line will connect to the existing
domestic water

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 22
	 	Contract DE-AM36-02NT41457

header located outside of the nearby industrial water treatment plant, located
approximately 0.3 miles east of the cogeneration facility. Domestic water usage is expected to be
minimal (5-10 gpm) and used for sink, lavatory, and maintenance requirements. Annual consumption
is expected to be approximately 2600 kilogallons (kgal). The domestic water interconnection will
be designed per M&O standards and permitted as required by the SCDHEC.

Process Water

River water will be used as the water source for all process and fire water. The process water
usage includes boiler feedwater, cooling tower makeup water, water treatment regeneration cycles,
and cogeneration facility service water. The river water will be supplied from Building 681-3G,
the water pump house, through an existing distribution system and pump station. A new 12” ductile
iron line will be routed underground from the existing C Area valve house (refer to Figure 1.6) to
the cogeneration facility site following the route of the abandoned steam line from the C Area, and
then diverting off of the route through existing vegetated areas to the site. Routing through the
vegetated area will reduce the new distribution pipe route by approximately 1/2 mile. The specific
routing is shown on the site drawing which is included in the drawing package (Volume III). The
peak make-up requirement to the site is 2200 gpm; this would occur if the system was operating at
full capacity and if all the regeneration cycles of the water treatment system were occurring at
the same time. Normal operations will use 600 gpm. Annual river water consumption will average
around 450,000 kgal.

To ensure there is adequate redundancy and back-up for the site river water source, in addition to
the installation of the new distribution line a new pump skid (identical to the P-10 skid) will be
installed to replace the pump, P-4, located inside the water pump house (Bldg 681-3G). The new
pump will be used as a backup for P-10 and be designed with a 19.8” impeller size (600 hp motor.)
Other components to be installed with the new pump include:

	 	l	 	 Rework of the existing suction pipe
	 
	 	l	 	 Installation of isolation valve in suction pipe
	 
	 	l	 	 Installation of flow control valve & flow meter
	 
	 	l 	 	Installation of instrumentation and valves setup (duplicate system to the P-10 skid)
	 
	 	l	 	 Control modification to allow the pumps to automatically operate based on
system requirements

Figure 1.6: Biomass Cogeneration Facility River Water Interconnection

[**]

Site Outfall

A new 24” high density polyethylene pipe will be routed from the cooling tower basin to Upper Three
Runs Creek. The pipe will be installed underground and follow the natural topography of the land.
A new outfall structure will be constructed next to the cooling tower to allow for flow monitoring
and effluent testing. Process waste water and the storm water runoff will be discharged to the
outfall. The storm water system includes collection piping to catch basins which will divert the
storm water to the site

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 23
	 	Contract DE-AM36-02NT41457

retention pond. The retention pond will discharge to the outfall. The
outfall will be permitted under the site National Pollutant Discharge Elimination System (NPDES)
permit.

Sanitary Sewer

The bathrooms and fixtures located in the cogeneration facility and in the administration building
will connect to the existing sanitary sewer system via a 4” polyvinyl chloride (PVC) pipe and be
pumped using a new lift station. The line will connect upstream to the 607-91G lift station
located approximately 0.3 mile east of the cogeneration facility. The sanitary sewer
interconnection will be designed per M&O standards and permitted as required by the SCDHEC. Annual
discharge is expected to be 2,600 kgal.

Electrical System

Power will be delivered to the existing F Area substation at 13.8 kV from the cogeneration
facility. The power feeder from the cogeneration facility will be approximately 7,600 feet and
will be routed in a combination of overhead pole mounted transmission line and underground duct
bank where required in the F Area. The feeder will connect to an existing spare breaker cell in
the metal-clad switchgear lineup at 251-F. The breaker cell shall be unit 101A, 101B, 206A, or
206B as deemed suitable by Ameresco and the Government. The interconnection scope of work includes
a compatible circuit breaker, multifunction utility-grade numerical relay and instrumentation, and
a 15kV class line potential transformer (PT) (either outdoor on feeder or indoor in a top-hat
structure added to the existing switchgear). Existing bus PT secondary sources and existing
station direct current (DC) battery sources are to be tapped as-is without improvement. Ameresco
will utilize as-is or improve existing lockout relays and circuit breaker auxiliary contacts where
no spare contacts or similar status points are available. Where such improvements are not possible
due to the limitations of existing equipment, Ameresco will propose a solution to the Government
(e.g. interposing relays, SCADA outputs, etc.). Ameresco assumes that the subject devices either
as existing or improved, sufficiently indicate the operation of distribution and transmission level
switching to determine when the generation system is unintentionally islanded from the utility
source. Where transfer trip capability is required or determined to be best practice for
protection of the proposed generation system, transfer trip facilities are to be derived from
existing utility protective relaying
equipment installed at 251-F. The scope excludes special or upgraded SCADA communications between
251-F and electrical utility operator. This scope is limited to the feeder circuit breaker at
251-F used to service the proposed generator plant and the primary protection described. The scope
does not include other feeders at 251-F or any other upstream devices that are not impacted by the
project (e.g. transformer secondary or primary protective devices and features, transmission-level
protective devices and features). To insure appropriate coordination with the existing F area
electrical distribution equipment, SRS will need to supply required load-flow, short-circuit, and
intertie relay settings. Ameresco will prepare a transient study if deemed necessary for
design.

Power at the new cogeneration facility is generated at 13.8 kV and is connected to a main 13.8
kV switchgear unit identified as “HVS”. “HVS” is equipped with six (6) breakers. Breaker “52G” is
utilized for the main generator breaker and is complete with required protective and synchronizing
relaying. Breaker “52-4160” feeds a 7500/9375 kilovolt amperes (KVA) transformer “ATX-2” that
steps down to 4160 volts alternating current (VAC) for large motor loads. Breaker “52-480” feeds a
2500/333 KVA

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	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 24
	 	Contract DE-AM36-02NT41457

 transformer “ATX-1” that steps down to 480 VAC for all the remaining facility power
distribution loads. Breakers “52-SG-1” and “52-SG-2” are utilized as feeders from two 1500 kW
standby generators. Breaker “52U” is the tie breaker that feeds power to and from the F Area.
This breaker will also be complete with all required protective and synchronizing relaying. The
13.8kV switchgear “HVS” and transformers “ATX1” and “ATX2” are located in the electrical room in
the new cogeneration facility.

D Area Electrical Feeder

A new feeder will be installed in the D Area to provide continued electrical service to both the D
Area and the TNX Area when the 484-D Power Plant is either dismantled or demolished and to reduce
the annual SCE&G costs associated with O&M of Station 41. The new feeder will be a #2 aluminum
conductor, steel reinforced (ACSR) overhead 13.8 KV 3 phase line that will run from the existing
overhead line in the vicinity of Barricade 3 at the entrance to D Area, down the east side of the
entry road to a point roughly 80’ short of the 115 KV line crossing, turn east and run across
country paralleling the 115 KV line just outside of its right of way (ROW) until it is terminated
with a tie-in to an existing 3 phase line crossing at the back of D Area. By connecting to this
line, the new feeder will be able to power the TNX complex without any further modifications to the
existing overhead system. Fused sectionalizing switches will be installed at each end of the new
line. The recloser currently installed back across the Highway on the line being tapped will be
recalibrated to reflect the addition of the line extension to D Area.

Before turning east at the 115 KV line, the new line will cross a CSX railroad main line. A
complete design/permitting package will be developed and submitted to the railroad for their review
and approval. Initial filing fees for this permitting process are included, but any ongoing fees
due CSX are excluded from this proposal and will be the responsibility of the Government.

The addition of this feeder will result in monthly O&M savings currently paid to SCE&G to maintain
the equipment in Station 41. The annual savings is $75,000 (10% reduction of the current O&M
charge to SCE&G).

L Area Capacitor Work

The single 6 megavolt ampere reactive (MVAR) capacitor bank currently sitting on the L Area site
will be installed on a new concrete pad in the grassy area across the access drive on the northwest
side of the switchgear building, and connected to existing breaker 2-6 within substation 151-1L.
New cable and cable tray will be installed in the basement beneath the switchgear to the northwest
wall where spare sleeves will be used to exit the building. A new underground duct bank will be
run from the building wall under the drive to the new pad for the capacitor bank connecting the
capacitor. Spare 4” conduits will also be provided stubbed out from beneath the new pad for future
connections to other systems. The capacitor bank will be interfaced with the existing SRS SCADA
system. The actual location in the grassy area will be coordinated with the proposed installation
of a future grounding transformer. The drive and associated curbs will be replaced after the duct
is installed.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 25
	 	Contract DE-AM36-02NT41457

We have been advised that several capacitor cells are defective. These will be replaced with
available spare cells to the extent possible. These are the only repair efforts included in the
installation of this capacitor bank which has been sitting out in the weather unprotected for some
time. Any other repairs necessary to get the bank into fully operational condition are not the
responsibility of Ameresco.

Installation of this existing capacitor bank will assist SRS in maintaining their power factor as
close as possible to the minimum required by the utility company before penalties are assessed.

1.2.4 Proposed Equipment

The proposed ECM 1 will include the major components as described in Section 1.1. An
equipment list and manufacturer’s literature for the boiler and turbine system is included in
Appendix C.

1.2.5 Expected Lifetime

The combustor/boiler and turbine components have an expected lifetime of 25-30 plus years.
Ameresco will repair and replace components to ensure the continuous operation of the equipment
throughout the contract performance period.

1.2.6 Physical Changes to Existing Equipment or Facilities

The cogeneration facility will be located on an unoccupied area of the SRS. The actual site
will not impact or require physical changes to the existing facilities; however, there are changes
required at other areas of the reservation as a result of operations of the new cogeneration
facility.

These include the following:

	 	l	 	 D-Area Electrical Feeder
	 
	 	l	 	 Pump and Controls Replacement in Building 681-3G, Water Pump Station
	 
	 	l	 	 Installation of existing capacitor at the L-Area Substation 151

1.2.7 Savings Proposed

The annual savings associated with ECM 1 are based on the avoided cost of operating and
maintaining the existing D Area Plant. The energy savings result from using a more efficient
boiler and steam distribution system and the energy cost savings from using biomass as the primary
fuel source in place of coal.

1.2.7.1 Annual Project Savings Overview

In order to calculate the annual savings, [**]. Thus, the annual savings from the ECM equals:

Annual Savings = [**].

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 26
	 	Contract DE-AM36-02NT41457

Annual savings [**]. Table 1.3 provides a summary of the annual Post-ECM Implementation Costs, as
escalated, that will be determined annually and Other Energy Savings and O&M Cost Savings, as
escalated, which are herein agreed to by the Government and Ameresco for the contract term
associated with ECM 1. [**] per year.

Table 1.3: ECM 1 Annual Savings Summary

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	Post-ECM	 	 
	 	 	Annual Utility	 	Annual O&M	 	Implementation	 	Total Annual
	 	 	Savings	 	Cost Savings	 	Costs	 	Savings
	Baseline Year
(CY 2009)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	30,658,617	 
	Escalated to
Project Year 1 (CY
2012)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	33,181,197	 
	Year 2
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	34,404,421	 
	Year 3
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	35,322,289	 
	Year 4
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	36,399,646	 
	Year 5
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	37,676,281	 
	Year 6
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	39,368,611	 
	Year 7
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	40,858,535	 
	Year 8
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	42,100,018	 
	Year 9
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	43,817,394	 
	Year 10
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	47,247,150	 
	Year 11
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	49,023,439	 
	Year 12
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	50,831,412	 
	Year 13
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	52,654,059	 
	Year 14
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	54,705,813	 
	Year 15
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	56,773,136	 
	Year 16
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	58,856,493	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 27
	 	Contract DE-AM36-02NT41457

Table 1.3: ECM 1 Annual Savings Summary

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	Post-ECM	 	 
	 	 	Annual Utility	 	Annual O&M	 	Implementation	 	Total Annual
	 	 	Savings	 	Cost Savings	 	Costs	 	Savings
	Year 17
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	60,921,492	 
	Year 18
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	63,483,800	 
	Year 19
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	65,849,637	 
	Year 20
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	68,447,514	 

The following subsections present the assumptions and methodology for establishing the
baseline cost and baseline energy consumption for the D Area Plant & Substation, the annual savings
calculations, and the performance guarantee for the proposed project.

1.2.7.2 Annual Energy Baseline Consumption & Costs

The D Area Plant uses [**]. The annual energy consumption and operations costs data for the
D-Area Plant was developed to [**] were escalated two years to accurately represent 2009 as the
baseline. Total O&M Cost Savings are escalated to 2012 dollars and are $[**]

Table 1.4: O&M Baseline Costs for D-Area Plant

	 	 	 	 	 	 	 	 	 	 	 	 	 
	Month	 	2006 O&M 

Costs	 	2007 O&M 

Costs	 	Baseline O&M 

Cost Savings
	January
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	February
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	March
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	April
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	May
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	June
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	July
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	August
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	September
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	October
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	November
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	December
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	 
	 	 	 	 	 	Total	 	$	10,692,844	 

 

			
	**	 	Data was not available, so used 2006 data with escalation on labor only
	 
	***	 	Data in this table is presented using 2006 & 2007 dollars and not Baseline year

The annual energy consumption for the D Area plant is based on the amount of coal utilized to
produce steam for SRS thermal demand and for SRS power supply. The baseline consumption was
determined using monthly averages for the latest two years of fuel usage data. The average annual
amount of coal

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consumed for the past two years was [**] tons, which is used as the agreed upon
energy savings baseline. The baseline for energy cost is determined by the product of the baseline
energy consumption times the baseline cost of coal. The baseline cost of coal, as provided by SRS
and agreed upon, is $[**] per ton of delivered coal. Thus the baseline energy cost is agreed to be
$[**]. Currently, all electric power required by the site above the net output of the D Area power
plant is procured from SCE&G under Rate Schedule 23 and Rate Schedule 60. The energy charge is
[**] per kWh and the average demand charge is $[**] per kW for load over 20 MW. The baseline power
export from the D Area plant was determined using monthly averages for the last two years of data.
Refer to Table 1.5 for a summary of the fuel consumption and the net power exported from the D Area
plant.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
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Table 1.5: Baseline Energy Consumption

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	2006 Energy Use	 	 	 	 	 	 	 	 	 	2007 Energy Use	 	 	 	 	 	 	 	 	 	Baseline Energy Use	 	 
	 	 	 	 	 	 	 	 	 	 	Net	 	 	 	 	 	 	 	 	 	 	 	 	 	Net	 	 	 	 	 	 	 	 	 	 	 	 	 	Net	 	 
	 	 	 	 	 	 	 	 	 	 	Output	 	 	 	 	 	 	 	 	 	 	 	 	 	Output	 	 	 	 	 	 	 	 	 	 	 	 	 	Output	 	 
	 	 	 	 	 	 	 	 	 	 	of D-	 	 	 	 	 	 	 	 	 	 	 	 	 	of D-	 	 	 	 	 	 	 	 	 	 	 	 	 	of D-	 	 
	 	 	Coal	 	 	 	 	 	Area	 	Power	 	Coal	 	 	 	 	 	Area	 	Power	 	 	 	 	 	 	 	 	 	Area	 	Power
	 	 	Use	 	Coal Use	 	Plant	 	Export	 	Use	 	Coal Use	 	Plant	 	Export	 	Coal Use	 	Coal Use	 	Plant	 	Export
	Month	 	(tons)	 	(MBtu)	 	(MWh)	 	(MW)	 	(tons)	 	(MBtu)	 	(MWh)	 	(MW)	 	(tons)	 	(MBtu)	 	(MWh)	 	(MW)
	January
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	February
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	March
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	April
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	May
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	June
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	July
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	August
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	September
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	October
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	November
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	December
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	Totals	 	 	 	 	 	 	 	 	 	 	161,839	 	 	 	3,978,008	 	 	 	131,889	 	 	 	 	 

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1.2.7.3 Annual Energy Savings Calculations

The annual savings are determined by calculating the baseline annual O&M cost for the existing
plant, plus the annual energy cost as presented in the previous section. The annual savings are
then adjusted to account for the cost to be incurred by SRS to purchase additional power from SCE&G
and to account for the Post-ECM Implementation Costs to be incurred by SRS for the non fuel
utilities of the new cogeneration facility.

The additional future cost of purchased electricity is calculated using the [**]

[**].

The annual savings are also adjusted to account for the Post-ECM Implementation Costs incurred by
SRS to provide non-fuel utilities to the new facility. This includes the cost for river water,
sanitary sewer, and for domestic water. The annual consumption for each of these utilities is
shown in Table 1.6.

The net estimated annual savings for ECM 1 is $33,181,197 for the first year of the performance
period (2012).

1.2.7.4 ECM 1 Performance Measurement

The ECM performance will be measured using the flow output (via a steam flow meter) of the two
biomass boilers. Measuring and totalizing the steam production permits for flexibility to make use
of this steam to meet the thermal and electrical demands of SRS while allowing for normal seasonal
variations and adjustments for expected future load changes. The Annual Steam Guarantee (ASG) for
ECM 1 will be 1,759,485 kilopounds per year (klbs/yr) of steam using an annual fuel consumption of
[**] MBtu/yr and is shown in Table 1.6 — ECM 1 Post-ECM Implementation Facility Performance. The
ASG will remain set throughout the performance period; however, the electrical output and the steam
export output will vary. Annual biomass costs are calculated based on meeting the ASG and will be
adjusted only when the actual steam production for ECM 1 exceeds the ASG; refer to Section 1.3.1.2.

Ameresco proposes to produce additional steam from the cogeneration facility above the ASG, unless
notified otherwise in writing by the contracting officer, provided that the Government compensates
Ameresco for the incremental cost of biomass annually. Additional steam may be used for power
generation or for thermal energy. Excess delivered steam above the ASG will be paid for by the
Government as described in Section 1.3. Further increase in green power generation due to excess
steam production will result in additional annual savings and will be documented in the annual M&V
report.

The planned Post-ECM Implementation Costs for Ameresco to operate and maintain ECM 1 are included
in the performance period expenses set forth on Schedule DO-3. The performance period expenses
include the costs necessary for Ameresco to provide operations and maintenance of the new
cogeneration facility including fuel (biomass and fuel oil for backup), personnel, daily operations
and maintenance, routine and non-routine repair and replacement costs, and operations management to
meet the ASG.

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Post ECM Installation Cogeneration Facility Performance

The data in Table 1.6 is derived from the output of energy modeling software (Thermoflex), from
vendor data for equipment efficiency, and from using the steam load data provided by the Government
(refer to Table 1.1). The following paragraphs are an overview of the general methodology of the
performance calculations.

Steam Use:

[**]

Power Generation:

[**]

Fuel Supply:

     [**].

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Table 1.6: ECM 1 Post-ECM Implementation Facility Performance

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Plant Parameter	 	Year 1	 	Year 2	 	Year 3	 	Year 4	 	Year 5	 	Year 6-9	 	Year 10-20
	Total Boiler Capacity Steam Load (k-lbs/yr)
	 	 	2,102,400	 	 	 	2,102,400	 	 	 	2,102,400	 	 	 	2,102,400	 	 	 	2,102,400	 	 	 	2,102,400	 	 	 	2,102,400	 
	Annual Steam Guarantee (k-lbs/yr)
	 	 	1,759,485	 	 	 	1,759,485	 	 	 	1,759,485	 	 	 	1,759,485	 	 	 	1,759,485	 	 	 	1,759,485	 	 	 	1,759,485	 
	Steam Use
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	SRS Export Steam Load (k-lbs/yr)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Steam Load for Power Generation (k-lbs/yr)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Aux Steam Load (k-lb/yr)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Power Generation
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Net Green Generation (kWh/yr)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Net Green Generation (MBtu/yr)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Baseline Power Export from D Area Plant (kWh/yr)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Post-ECM Implementation Electricity Purchased from SCE&G (kWh/yr)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Post-ECM Implementation electricity Purchased from SCE&G ($/yr)
(*see note)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Fuel Supply
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Annual Fuel Consumption for ECM 1 (MBtu/yr)
	 	 	2,727,205	 	 	 	2,727,205	 	 	 	2,727,205	 	 	 	2,727,205	 	 	 	2,727,205	 	 	 	2,727,205	 	 	 	2,727,205	 
	Fuel Required for ECM 1, 100% Biomass (tons/yr)
	 	 	317,118	 	 	 	317,118	 	 	 	317,118	 	 	 	317,118	 	 	 	317,118	 	 	 	317,118	 	 	 	317,118	 
	Fuel Cost for ECM 1, 100% Biomass ($/yr) (**see note)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 

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Table 1.6: ECM 1 Post-ECM Implementation Facility Performance

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Plant Parameter	 	Year 1	 	Year 2	 	Year 3	 	Year 4	 	Year 5	 	Year 6-9	 	Year 10-20
	Post-ECM Non Fuel Utilities ***
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	River Water (k-gals/yr & $/yr)
	 	

$	460,215

(346,699	)	 	

$	456,015

(353,842	)	 	

$	459,033

(366,869	)	 	

$	460,261

(378,886	)	 	

$	457,981

(388,319	)	 	

$	461,026

(402,627	)	 	

$	454,418

(446,666	)
	Domestic Water (k-gals/yr & $/yr)
	 	

$	456

(4,692	)	 	

$	456

(4,833	)	 	

$	456

(4,978	)	 	

$	456

(5,128	)	 	

$	456

(5,281	)	 	

$	456

(5,440	)	 	

$	456

(6,123	)
	Sanitary Sewer 

(k-gals/yr)
	 	

$	456

(3,621	)	 	

$	456

(3,730	)	 	

$	456

(3,842	)	 	

$	456

(3,957	)	 	

$	456

(4,076	)	 	

$	456

(4,198	)	 	

$	456

(4,725	)

 

			
	*	 	The power purchased cost is per 2009 unit cost, however the DO schedules are escalated per
NIST to account for future price of power.
	 
	**	 	Annual biomass cost for years 7-9 and 11-20 are not shown in this table, but escalated from
previous year using an escalation factor of 5%
	 
	***	 	Non fuel utility consumption is calculated on full load on expected maximum each year so the
consumption is constant throughout the term; the actual cost is escalated each year.

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1.2.8 Utility Interruptions

The utility interconnections are described in detail in Section 1.2.3. It is anticipated that
these connections will be made with minimal interruption to the SRS site. Any necessary
interruptions will be coordinated and scheduled in advance with SRS personnel and with M&O site
personnel. The shutdown of the D area plant and the start-up of the new cogeneration facility will
be coordinated with SRS personnel and D Area site personnel to allow for minimal interruptions
during transition.

1.2.9 Agency Support Required

Ameresco will continue to work with the Government as the project moves through the final
design and the construction period. Support from the Government’s engineering, contracting, and
maintenance units, as well as management will be required for continued success of the proposed
project. The Government, through its M&O Contractor Environmental Support Section will be
responsible for processing the storm water management permit, the final site use permit, the
National Environmental Policy Act (NEPA) document, domestic water permit, sanitary sewer permit,
wetland permit, and the new outfall into the site NPDES Permit. Refer to Section 3.2 for a
description of the environmental permit and documentation required for this ECM.

1.2.10 Potential Environmental Impact

Refer to Section 3.0 for environmental benefits and impacts from both ECMs.

1.2.11 ECM Property Ownership

As approved under the BAMF Contract, title to all contractor-installed equipment proposed
under this ECM will vest with the Government upon its acceptance of such ECM or the date that
commercial operations begin, whichever occurs earlier.

1.2.12 ECM Project Schedule

The construction schedule will be developed using Primavera P-6 software and submitted to the
contracting officer. The following table shows the major milestones of the design and construction
period.

Table 1.7: Project Milestones

	 	 	 	 	 	 	 	 	 
	Activity	 	ECM 1	 	ECM 2
	Site Work
	 	 	09/01/09	 	 	 	07/01/09	 
	Site Utility*
	 	 	09/01/09	 	 	 	09/01/09	 
	Concrete/Foundation Work
	 	 	12/01/09	 	 	 	11/01/09	 
	Building Package
	 	 	06/01/10	 	 	 	01/01/10	 
	Mechanical Install Work
	 	 	06/01/10	 	 	 	05/01/10	 
	Process Piping Work
	 	 	08/01/10	 	 	 	05/01/10	 
	Electrical Plant Work
	 	 	12/01/10	 	 	 	05/01/10	 
	Instrumentation & Controls Work
	 	 	12/01/10	 	 	 	05/01/10	 
	Insulation Work
	 	 	12/01/10	 	 	 	05/01/10	 
	Start up & Commissioning
	 	 	06/01/11	 	 	 	07/01/10	 

 

			
	*	 	Design Packages to be submitted throughout the first year of project

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1.3 BAMF Project Components

1.3.1 BAMF Resource

ECMs 1 and 2 will require approximately 322,118 tons of forest residue biomass per year to
meet Ameresco’s ASG and approximately 385,000 tons of forest residue biomass per year to operate at
design capacity. For such calculation of tons, Ameresco used a heating value of 4,300 Btu/lb from
forest residue. Ameresco intends to procure both clean biomass and biomass derived fuel (BDF).
Clean biomass includes forest residues, some urban waste, untreated wood pallets, and residue from
lumber processes. BDF includes urban wood waste and tire derived fuel and will only be used in
connection with ECM 1. There are numerous sources of clean biomass within a 100 mile radius of the
SRS site, including within the SRS Forest. The following sections describe available BAMF supply,
BAMF pricing, and BAMF acquisition.

1.3.1.1 BAMF Supply

Following several discussions with the local office of the U.S. Forest Service and SRS
personnel, Ameresco proposes to assume responsibility for the fuel procurement and intends to meet
the biomass fuel requirements for ECMs 1 and 2 through purchases from local biomass suppliers.
This responsibility shall include the right to validate, verify, and sell any carbon credits, but
not renewable energy certificates, which may be obtainable from the ECMs and their associated
operation and activities. Ameresco will consult with the Government concerning the design,
validation, and verification for carbon offset credits and will make reasonable commercial efforts
to obtain carbon offset credits which may be associated with the ECMs. Those credits may arise
from the substitution of biomass residues for use in lieu of fossil fuels, and the use of biomass
from onsite activities, including those from forest reforestation and working forest activities.

BAMF Deliveries

There will be deliveries of biomass and other BAMF fuel scheduled daily, Monday through Friday
(normal operations), throughout the contract performance period. It is estimated that up to 60
trucks may enter and depart the C and Burma Road location each day, five days per week. It is
anticipated that deliveries will be accepted from 7:00 AM to 7:00 PM although the exact hours may
vary by season and/or supplier. Acceptable delivery hours will be established with each biomass
supplier. Following meetings with SRS personnel, Ameresco has agreed to minimize the number of
deliveries departing the site at the C Road traffic signal from 6:30 to 8:30 AM to accommodate
arriving SRS personnel turning left at that traffic signal. Ameresco has been given assurance, and
this proposal is predicated upon biomass delivery vehicles being permitted to enter and depart the
SRS reservation at any of the available (open) gates and not be limited to just the Aiken and
Jackson Barricades.

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Drivers of the BAMF delivery vehicles will be required by Ameresco to obtain a permanent (one year)
site badge and to comply with SRS vehicle safety and site entry requirements, except as noted
above.

Ameresco has conducted many discussions and met with potential fuel suppliers within the past few
months. Ameresco is currently working primarily with [**].

[**] as described below.

1.3.1.2 BAMF Pricing

Ameresco’s annual expense [**]

The intended purpose in establishing the [**].

	(c)	 	To the extent that Ameresco’s [**]
	 
	(d)	 	To the extent that Ameresco’s [**]
	 
	(e)	 	Ameresco, upon [**] Ameresco may [**].

1.3.1.3 BAMF Acquisition

Ameresco may enter into an agreement with one or more biomass suppliers. Ameresco will also
attempt to secure from each supplier a fixed fuel price for as long a term as possible.

1.3.2 BAMF Transportation, Metering, & Delivery

1.3.2.1 BAMF Transportation & Delivery

The biomass will be delivered from the suppliers using trucks with live bottom feeders,
self-dumping trucks, or trucks with high-side trailers. Typically, each of the larger trucks has
the capacity to hold approximately 120 cubic yards of fuel per load. The smaller self dumping/end
dump trucks typically only carry about 50 cubic yards of fuel and will be used primarily for BDF
waste sources or for larger unprocessed fuel. Actual loads may vary with the density of the fuel.
Normal truck deliveries will be arranged to be made Monday through Friday.

1.3.2.2 BAMF Metering

Woodwaste is commonly measured in units of weight and volume such as in tons, truck loads, or
cubic yards, rather than in units of energy. For this proposal, the higher heating value of
biomass is about 4,300 Btu/lb since the majority of the fuel will be from forest residues and is
typically high in moisture. The fuel supply will be tracked and recorded using the truck scale
tickets. Periodic testing will be done on the fuel to determine the composition and the heating
value.

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1.3.3 BAMF End-Use Project

1.3.3.1 BAMF End-Use Demand

End use of the biomass source was calculated utilizing forest residue as the main fuel source
to meet the ASG. Forest residues for the Carolina area are typically high in moisture with heating
values in the range of 4,100-4,600 Btu/lb. For the design basis and end use demand calculations, a
higher heating value of 4,300 Btu/lb was used to determine boiler feed input. At this heating
value, the boiler efficiency is expected to be 70%. At these conditions, the expected annual fuel
use for ECM 1 is 317,118 tons a year of biomass consisting of forest residues.

1.3.3.2 BAMF End-Use Operations & Maintenance

Ameresco will retain operational and maintenance responsibility for the cogeneration facility
and equipment installed at the cogeneration facility, described in Section 5.2.7.1 of this
proposal.

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2.0 ECM 2 DESCRIPTION

2.1 ECM Summary Schedule DO-4

Pricing Schedule DO-4 is included in Section 6.0, Proposal Pricing Information.

2.2 ECM #2:Biomass Heating Plants for K& L Areas

2.2.1 Detailed Description of ECM

2.2.1.1 ECM Summary

ECM 2 includes the installation of biomass heating plants in the K Area and the L Area. These
new heating plants will replace the existing fuel oil-fired boiler plant located in the K Area that
currently serves heating loads in both the K and L Areas. The two existing 30,000 and 60,000 lb/hr
steam boilers are in poor condition and are now vastly oversized for the current load (estimated by
SRS personnel to be approximately 7,000 PPH of steam in each area at design conditions). The
existing 30,000 lb/hr boiler has been utilized as the primary boiler during the most recent years,
due to the large reduction in load from the original design. Currently steam is produced at 150
psig to distribute to the K and L Areas and reduced inside the secure areas for use at 30 psig or
less. By decentralizing the existing plant and providing local boiler systems in both the K and L
Areas, the losses from the existing aboveground 2.5 mile, 6-inch steam line running from the K Area
to the L Area will be eliminated. Additional efficiency gains are made from the right-sizing of
the new heating plants to match existing loads.

The heating plants are each sized to provide a continuous availability for supply of steam to site
end-users in the K and L areas during the typical heating season of December through mid April.
The individual site demand was based on fuel oil consumption data for the past 5 years. The system
is designed using applicable national codes and standards for steam plants and specific site
standards (refer to Appendix D). Previously, conceptual design drawings were submitted to the site
for review prior to issuance of this final proposal; a draft version of the “issued for pricing”
drawings is included in Volume III of this proposal. Finalized “issued for construction” drawings
will be submitted to the government for concurrence throughout the first year of the construction
as major equipment items are ordered and the design drawings are finalized.

Implementation of this project provides utility savings resulting from 1) The elimination of losses
from 2.5 miles of existing steam distribution piping between the K and L Areas; and 2) Improved
operations from properly sized boilers, and the fuel cost differential in switching from fuel oil
to clean biomass. Annual savings are over $1.1 M for this ECM.

This proposal includes the procurement and installation of the new equipment, the support
facilities, all auxiliary systems and controls, and utility tie-ins required to connect the new
heating plants to the K and L Area distribution systems, as well as ongoing O&M and environmental
compliance of both heating plants for the contract duration.

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2.2.1.2 ECM Process Description

This ECM includes two major components for each of the proposed heating plants: 1) Biomass
fuel storage system, and 2) combustion/boiler system. Each new heating plant will be installed in
an enclosed building with an adjacent covered shelter to house the wood fuel storage and delivery
equipment. Biomass fuel will be delivered to both heating plants by Ameresco personnel from the
fuel processing yard of the Biomass Cogeneration Facility. The fuel delivered to each of these
heating plants will be clean biomass (refer to Section 1.3). The clean biomass will be used as the
primary fuel source for two new wood waste combustor boilers to supply steam to the K and L Areas.
Each boiler system will be designed to generate 10,500 PPH of saturated steam at 135 psig.

Biomass Fuel Storage System

The fuel storage area consists of the storage system and feeder to the combustion system. The
components of this system are recommended to minimize equipment at each site and to provide maximum
automation to each of the heating plants. Ameresco personnel will employ tractor-trailers to
transfer the biomass fuel from the fuel yard at the cogeneration facility to both the K and L Area
heating plants. The tractor-trailers will be parked in the new fuel storage shelter bays, one at
each heating plant location. Each tractor-trailer is equipped with a walking floor-bed
installation for the automated transfer of fuel to the stationary metering bin at each heating
plant. The metering bin utilizes augers to feed the fuel into the combustion system.

The flow of fuel is controlled by an integrated direct digital control (DDC) system that automates
the flow of fuel from the walking-bed to the metering bin, and from the metering bin to the
combustor, based on input signals (and required safeties) to maintain steam pressure at the output
of the boiler.

Fuel Storage System components for each area (K and L) includes:

	 
	 	l	 	Tractor trailer with walking bed for fuel feed     
	 
	 	l	 	Fuel storage shelter bay     
	 
	 	l	 	Main fuel bin and auger to feed combustor     

Combustion/Boiler System

One combustion/boiler system will be located in each area, in a separate, enclosed bay connected to
the fuel storage shelter bay. The system proposed is manufactured by Hurst Boiler & Welding
Company, Inc., and is designed specifically for the combustion of solid waste fuels to optimize
energy recovery and minimize air emissions. Refer to Appendix C for manufacturer cut sheets.

When there is a demand for steam the biomass is augered from the fuel storage bin into the
combustor, where the biomass begins to burn by the use of three levels of air directed into the
combustion zone. The primary air is forced into the combustion zone from beneath the fuel grates
(on which the fuel rests during combustion). The secondary air is forced through side grates, and
the tertiary air comes through the side

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of the cast refractory to keep unburned ash from exiting the unit. The primary combustion zone is
lined with high-insulating value, cast refractory ceramics to minimize radiant heat losses from the
unit exterior.

A similar, secondary ceramic chamber fired at 3,100°F is included between the primary combustion
zone and the boiler to allow for an extended combustion zone. The extended retention time in the
secondary zone ensures the additional combustion of the biomass and reduces emissions. The
appropriate combustion temperature is maintained by adjusting fuel feed, fan speed, and air intake.

Each boiler will be equipped with an auxiliary burner to allow for the firing of fuel oil for full
output capacity of the boiler. Fuel oil will be used for pilot lighting on startup, and as a
back-up emergency fuel source only. Each boiler has the capacity to produce up to 10.5 k-lb/hr of
135 psig steam when the combustion system is operated at full output. Each is a 2,600 sq ft unit,
with 2 pass design and includes standard instrumentation, rear furnace access door, and
air-operated soot blowers. Downstream of each steam boiler, the exhaust gas will go through a
multi cyclone which reduces the particulate matter in the exhaust gas by 70%. The exhaust stacks
will be equipped with appropriate lighting as required for on-site helicopter travel.

Boiler/Combustion System components for each area include:

	 
	 	l	 	Metering Bin Feeder     
	 
	 	l	 	10.5 MBtu/hr combustion unit     
	 
	 	l	 	Full-capacity fuel oil burner     
	 
	 	l	 	Steam heat recovery boiler     
	 
	 	l	 	Multi cyclone     
	 
	 	l	 	SCADA system     
	 
	 	l	 	Automated ash removal system     
	 
	 	l	 	Exhaust stack with aviation lights     
	 
	 	l	 	Boiler auxiliaries     
	 
	 	l	 	Air compressor for L Area     
	 
	 	l	 	Water treatment skid for L Area     
	 
	 	l	 	Fuel Oil Storage     

2.2.1.3 ECM Operation

Ameresco will be responsible for operating and maintaining the heating plant facilities and
equipment throughout the contract term. Both boilers will be operated by Ameresco as needed to
meet the steam demand as more fully described in Section 2.2.7.3.

Both heating plants will be remote monitored via a telephone modem and using the Site PA system
from the control system at the cogeneration facility. Maintenance and inspection of the systems
will be performed by Ameresco operations personnel from the cogeneration facility. Refer to Table
2.1, which

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defines the interconnection and utility O&M responsibility for this ECM. Refer to Section 5.2.7.1
for a detailed description of the O&M responsibilities of each party.

2.2.2 Location Affected

The biomass heating plant at the K Area will be constructed in the same vicinity as the
existing plant, behind the two existing 30,000 gallon fuel oil tanks. The existing fence will be
modified to allow for the construction of a new gate which the biomass delivery trucks will use for
accessing the heating plant. A new facility will be constructed to house the biomass heating
plant, while the biomass fuel storage and feeder area will be located under a covered bay attached
to the new heating plant. For the L Area, a replica of the K Area heating plant will be installed
northeast of the abandoned cooling water basin. The footprint for each system is approximately
2,600 square feet, including an enclosed sound proof control booth. Refer to Figure 2.1and Figure
2.2 for site location plans for each area.

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Figure 2.1: K Area Biomass Heating Plant Location

[**]

Figure 2.2: L Area Biomass Heating Plant Location

[**]

2.2.3 ECM 2 Interface with Government Equipment

Title to all Ameresco installed equipment will transfer to the Government at the time of
Government acceptance of an ECM. For the sake of clarity, ECM 2 will interface with existing
Government equipment at the utility interconnections as described in this section. The
installation of utility interconnections required for the new heating plants are included in the
project implementation cost and the installation will be Ameresco’s responsibility; however, the
SRS M&O Contractor will retain O&M responsibility including repair and replacement for the utility
interconnections and utility distribution systems. Table 2.1 provides a summary of the utility
interface and the scope of O&M responsibility for the utility systems. Ameresco and the SRS M&O
Contractor will enter into an agreement that will provide the heating plants with utility services
to include river water, process sewer service, backup electrical power, and domestic water service.
A PSUP form will be completed by Ameresco prior to construction of utility interconnections.
Utility meters will be installed to measure usage. It is proposed the Government will incur the
cost for the cogeneration facility’s non fuel utilities. These Post-ECM Implementation Costs have
been factored into the annual savings. The annual consumption and costs of the utilities are shown
in Table 2.5, and the unit cost used for each utility is shown in Table 4.2. Refer to Section
5.2.7.1 for operation and maintenance responsibility.

Table 2.1: Utility Interconnection Summary

	 	 	 	 	 
	Utility	 	Interconnection	 	O&M Responsibility
	Steam

	 	New 6” 150 psig to
existing steam line
(PRV station in K
Area)
	 	Ameresco: to new
valve located in new
line just prior to
POIC with existing
steam line; SRS:  downstream of valve.
	 
	 	 	 	 
	Domestic water (K &

L Area)

	 	30 gpm, new 2” line
from plant to header
located outside
existing water treatment plant. A
new 2” line will be
installed from the
domestic water header
to the L Area heating
plant to be used as a
backup source for
feedwater and as a
source for the safety
shower and eyewash.
	 	Ameresco: to new
utility valve outside
of water treatment
building; SRS:  downstream of tie-in.
	 
	 	 	 	 
	River water (L Area)

	 	New 4”, 30 gpm, line
from river water
header in L Area
	 	Ameresco: to new
valve located in new
line outside of
heating plant; SRS: upstream of utility valve.
	 
	 	 	 	 
	Process Sewer

	 	2” connection to
existing line to Ash
Basin for K Area & 2”
connection to basin to L-07 outfall for L
Area
	 	Ameresco: to new
valve located in new
line outside of
heating plant; SRS:   downstream of utility
valve. (Ameresco
responsible for
meeting discharge
emission requirements
of these lines from
the K and L heating
plants)

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	Revised Final Proposal — May 11, 2009

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	 	Biomass Cogeneration Facility and Heating Plants

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Contract DE-AM36-02NT41457

	 	 	 	 	 
	Utility	 	Interconnection	 	O&M Responsibility
	Electrical

	 	New line from 151-2K
in K Area and add new
line from 183-2L to
the heating plant for
the L Area
	 	Ameresco: from
connection at heating
plant; SRS: upstream
of each heating
plant.
	 
	 	 	 	 
	Telephone Line/PA
System

	 	Verizon New Line
	 	Verizon/Ameresco

Electrical System

K Area: At the time Ameresco performed the initial field survey, SRS staff were beginning the
process of designing a dedicated overhead 300A, 480V feeder and panel board. This system has not
been installed to date, so a new feeder from the 151-2K substation will be provided as part of the
ECM 2 work scope. New motor control center(s) and associated low-voltage distribution equipment,
lighting, and related requirements associated with the new boiler and fuel handling equipment will
be provided.

L Area: Based on information provided by SRS, the switchgear, 183-2L is available for
interconnection and has adequate capacity for the load of the heating plant. Ameresco will run a
new feeder from 183-2L to serve a new overhead wood-pole distribution line to the proposed boiler
plant site. A new feeder will supply the motor control center and distribution panel(s) required
for the new equipment.

Steam Distribution System

K and L Area: Each new boiler will be connected to the existing steam distribution lines within
each area. The new boiler system will operate at 135 psig and pass through the existing PRV
station for distribution to end users at 30 psig.

Boiler Feedwater

K Area: Existing boiler feedwater services will be utilized for the new heating plant. Ameresco
will use and maintain the existing water treatment system. If the existing well water treatment
plant is not upgraded to produce domestic water prior to project startup, a small water tank will
be installed to hold domestic water for use in the safety shower and eye wash station.

L Area: River water will be used as the source for boiler feedwater for the heating plant. There
will also be a domestic water feeder used as a backup source for boiler feedwater and to feed the
safety shower and eyewash. A new water treatment facility will be installed to treat the water for
suitability of the new biomass boiler.

Process Sewer

K Area: The boiler blow down will connect to the process sewer system that runs to the existing
ash basin.

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L Area: The boiler blow down will be discharged to the existing L-07 Outfall. Ameresco will be
responsible for ensuring this (L Area heating plant) effluent is compliant with the NPDES Site
Permit.

2.2.4 Proposed Equipment

The proposed equipment is described in the previous section and an equipment list and
manufacturer information for the combustor/boiler system is included in Appendix C.

2.2.5 Expected Lifetime

The major equipment components have an expected lifetime of 20 — 30 years. Annualized repair
and replacement costs have been included in this proposal. Ameresco will be responsible for all
repair and replacement required to maintain heating plant operation.

2.2.6 Physical Changes to Existing Equipment or Facilities

Both proposed heating plants will be located outside of the process areas; however, this ECM
proposes to make the following modifications within the K Area:

	 	l	 	The K Area water treatment building will be left in place and existing water
treatment components will be utilized. Ameresco will maintain the water treatment equipment
and building throughout the term of this contract.
	 
	 	l	 	The air compressor located next to the existing fuel boilers in the K Area will
be used for the new biomass combustor system. Ameresco will maintain the air compressor
throughout the contract term.

2.2.7 Savings Proposed

The annual savings associated with this ECM are based on the avoided cost of operating and
maintaining the existing K Area Plant including the distribution system between the K and L Area,
the annual energy savings resulting from using a more efficient boiler, and by using biomass
instead of fuel oil as the primary fuel source. Additional energy consumption savings will be
realized by replacing the K Area plant with two smaller heating plants, which eliminates the 2.5
mile distribution line between the two areas.

Table 2.2 summarizes the annual savings associated with ECM 2. Annual Energy Savings [**]. Annual
Energy Savings and O&M Cost Savings shown on Table 2.2 are herein agreed to by the Government and
Ameresco for the term of the contract.

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	Revised Final Proposal — May 11, 2009

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Table 2.2: ECM 2 Annual Savings Summary

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	Post-ECM	 	 
	 	 	Annual Energy	 	Annual O&M Cost	 	Implementation	 	Total Annual
	 	 	Savings	 	Savings	 	Costs	 	Savings
	Current Year
(FY 2009)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,188,383	 
	Escalated to
Project Year 1 (FY
2012)
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,171,260	 
	Year 2
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,182,735	 
	Year 3
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,207,952	 
	Year 4
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,233,416	 
	Year 5
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,245,632	 
	Year 6
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,284,832	 
	Year 7
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,324,974	 
	Year 8
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,385,220	 
	Year 9
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,446,124	 
	Year 10
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,481,648	 
	Year 11
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,537,014	 
	Year 12
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,593,421	 
	Year 13
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,643,974	 
	Year 14
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,708,160	 
	Year 15
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,773,132	 
	Year 16
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,832,320	 
	Year 17
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,898,294	 
	Year 18
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	1,972,045	 
	Year 19
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	2,053,597	 
	Year 20
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$	2,129,145	 

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Contract DE-AM36-02NT41457

2.2.7.1 Annual Energy Savings

The annual savings are based on the avoided cost to operate and maintain the K Area plant
including the distribution system between the K and L Area and the cost of energy required to
produce steam in the existing boilers minus the Post ECM cost of the non fuel utilities for each
heating plant. The savings will be applied to fund the capital cost of the project and to fund the
ongoing performance period expenses throughout the contract performance period term. The
performance period expenses include the costs to operate and maintain the new heating plants such
as biomass and fuel oil cost, labor cost, consumable costs, maintenance costs, repair and
replacement cost, and operation management. The following subsections show the baseline cost and
energy consumption for the existing K Area Plant, the calculations of fuel and operating costs of
the new heating plants, and the savings summary for the proposed project.

2.2.7.2 Annual Energy Baseline Consumption & Costs

Currently the K Area plant utilizes one 60,000 lb/hr fuel oil boiler and one 30,000 lb/hr fuel
oil boiler to serve both the K Area and the L Area facilities via a 2.5 mile steam pipeline. Data
provided by SRS indicates that the 30,000 lb/hr boiler is the primary boiler, with the 60,000 lb/hr
not having run in the past 3 years. Steam is produced at 150 psig and is reduced to an operating
pressure of 30 psig for each site. The existing boilers are oversized and past their useful life,
and are currently a costly maintenance issue.

In order to calculate the annual savings for this ECM, a baseline was developed to depict the most
reasonable representation of the annual energy determined by taking the average consumption of the
past 5 years, and to determine the annual O&M costs which were based the average of the past 5
years as shown in the following tables:

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

Table 2.3: Baseline Operating and Maintenance Cost for K Area Plant

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	O&M Expense	 	2003	 	2004	 	2005	 	2006	 	2007	 	Baseline 

Year (2009)	 	Average Annual
 Costs
	Labor Total
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Material Total
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Other Consumable
Total
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Steam Distribution
O&M
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Subcontracts for
Repair &
Replacement
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Overhead for O&M
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 
	Total O&M Cost
Savings
	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	 	[**]	 	 	$551,189

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

Table 2.4: Baseline Annual Energy Consumption for K Area Plant

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	K Plant Production	 	2003	 	2004	 	2005	 	2006	 	2007	 	Average
	Fuel Use
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Fuel Use Gallons
	 	 	345,594	 	 	 	380,806	 	 	 	343,987	 	 	 	277,061	 	 	 	200,707	 	 	 	309,631	 
	Fuel Use MBtu
	 	 	47,865	 	 	 	52,742	 	 	 	47,642	 	 	 	38,373	 	 	 	27,798	 	 	 	42,884	 
	Steam Production
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Total k-lbs/yr
	 	 	36,648	 	 	 	40,382	 	 	 	36,478	 	 	 	29,381	 	 	 	21,284	 	 	 	32,835	 
	Hours in Season
	 	 	3264	 	 	 	2904	 	 	 	3264	 	 	 	2424	 	 	 	2112	 	 	 	2,794	 
	Average Load lbs/hr
	 	 	11,228	 	 	 	13,906	 	 	 	11,176	 	 	 	12,121	 	 	 	10,078	 	 	 	11,754	 

Using the past 5 years of data for fuel oil consumption, the annual average consumption is
309,631 gallons. The current price of fuel oil is $2.13 per gallon; therefore, the baseline energy
cost is $659,514.

The annual savings for ECM 2 are equal to the O&M cost savings plus the annual energy costs
baseline minus the post-ECM non-fuel energy costs. The annual savings for ECM 2 is $1,188,383 for
the current year and $1,171,260 for Year 1 (2012).

2.2.7.3 Annual Heating Plant Performance

For ECM 2, heating plant performance is based on heating plant availability to provide steam
to the K and L Areas, with outages no longer than a period of a week (seven continuous days) at any
one time, during the typical heating season of December through April up to a maximum of 33,300
klbs/yr (Availability Guarantee). The annual fuel cost for this ECM has been calculated using an
annual steam production of 33,300 klbs. If the steam load for the heating season is lower than
33,300 klbs and therefore the fuel consumption is lower, the difference will be reconciled as
described in Section 1.3. It is expected there will be a reduction of 10% of the steam load due to
the shutdown of the steam line between the two areas. If the steam production is higher due to an
increase in either Area’s demand, the fuel cost will be adjusted annually. Annual fuel costs are
calculated based on meeting the Availability Guarantee and will be adjusted annually on actual
steam production and actual fuel consumption (Refer to Section 1.3). The expected heating plant
performance is shown in the following table:

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	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

Table 2.5: ECM 2 Post ECM Heating Plant Performance

	 	 	 	 	 
	 	 	ECM Post-ECM	 
	Heating Plant Parameter	 	Performance	 
	Typical Operation
	 	December- April 15	 
	Expected Steam Production (k-lbs/yr)
	 	 	33,300	 
	Fuel Required for ECM 2, 100% Biomass (MBtu/yr)
	 	 	42,844	 
	Fuel Required for ECM 2, 100% Biomass (tons/yr)
	 	 	5,000	 
	Fuel Cost for ECM 2, 100% Biomass ($/yr) 2009
	 	$	110,000	 
	Fuel Cost for ECM 2, 100% Biomass ($/yr) 2012 — Year 1
	 	$	120,200	 

The non-fuel utilities consumed at each of the heating plants are to be incurred by the
Government. The Post-ECM implementation cost has been deducted from the annual savings for each
year of the performance period. The water consumption is based on the Availability Guarantee and
the electricity consumption is based on the load of the heating plants for the typical heating
season. The annual utility cost was calculated by multiplying the consumption by the unit cost of
the utility (refer to Table. 4.2). The unit cost of the utilities is escalated using the NIST
values and the [**]% escalation for the water cost.

Table 2.6: ECM 2 Annual Post ECM Non-Fuel Utilities Cost & Consumption

	 	 	 	 	 	 	 	 	 
	Utility	 	Annual Consumption	 	Annual Cost
	Domestic Water
	 	2,004 k-gal/yr	 	$	22,861	 
	River Water
	 	2,004 k-gal/yr	 	$	922	 
	Electricity
	 	345,600 kWh/yr	 	$	32,141	 

2.2.8 Utility Interruptions

The utility interconnections are described in detail in Section 2.2.3. It is anticipated that
these connections will be made with minimal interruption to SRS functions. Any necessary
interruption will be coordinated and scheduled in advance with site personnel.

2.2.9 Agency Support Required

Ameresco will continue to work with the Government as the project moves through the final
design and the construction period. Support from the Government’s engineering, contracting, and
maintenance units, as well as management will be required for continued success of the proposed
project.

2.2.10 Potential Environmental Impact

Refer to Section 3.0 for environmental benefits and impacts for both ECMs.

2.2.11 ECM Property Ownership

As approved under the BAMF Contract, title to all contractor-installed equipment proposed
under this ECM will vest with the Government upon its acceptance of such ECM, or the date that
commercial

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	Ameresco Federal Solutions
	 	Savannah River Site
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operations begin, whichever occurs earlier. Refer to Section 5.2.7.1 for an explanation of O&M
responsibilities.

2.2.12 ECM Project Schedule

A detailed project schedule (in Primavera) will be issued to the Government following contract
award.

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	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

3.0 ENVIRONMENTAL IMPACT OVERVIEW

By utilizing on and off site biomass sources (rather than coal and fuel oil) to produce steam
and energy, the proposed ECMs will provide a positive impact the environment. However, since both
ECMs introduce new equipment and structures onto the site/area, assessments and permits are
necessary in order to comply with the applicable local, state, and federal requirements. The
positive impacts and benefits of the project are highlighted in Section 3.1. Section 3.2 describes
the environmental permitting required by the SCDHEC and other required environmental documents.

3.1 Overview of Environmental Benefits

	 	l	 	The proposed plants will decrease the overall air emissions rates for 1)
particulate matter (PM) by more than 400 tons a year, 2) nitrogen oxides (NOx) by more than
2,500 tons a year, and 3) Sulfur Dioxide (SOx) by more than 3,500 tons a year. This will
result in a positive impact to the air quality of the local area.
	 
	 	l	 	Both ECMs will reduce energy consumption by eliminating over 6 miles of steam
distribution lines (3.5 miles for ECM 1 and 2.5 miles for ECM 2). The reduced steam
distribution pipe will decrease fuel consumption by at least 10% from reduction of in-line
steam losses.
	 
	 	l	 	The proposed cogeneration facility will decrease the amount of river water
currently drawn from the Savannah River by over 1,412,000 kgal per year. This is
especially significant as the level of the Savannah River is low and this project will
support efforts to protect the water level.
	 
	 	l 	 	 By replacing fossil fuels with a renewable energy fuel source, green house gas
emissions will be reduced by at least 100,000 tons a year significantly decreasing the
carbon footprint of the SRS.
	 
	 	l	 	 Although cogeneration facility and heating plants are not practical feasible
buildings for Leadership in Energy and Environmental Design (LEED) certifications, both
ECMs will incorporate sustainable design methods and incorporate energy efficient
technologies into the design.

3.2 Overview of Environmental Permitting &
Assessment

Since the proposed projects will be located at a new site and/or require the installation of
new equipment there will be new emission sources for air, water, and waste water. The resulting
emissions require environmental permits through the Environmental Protection Agency (EPA), SCDHEC,
and SRS. The following table is a summary of the permits required for the project, the status of
the permit, and the expected issuance of the permit. Each of these is further described in the
paragraphs below. The schedule and proposal are based on the dates in the table; significant
deviation of these dates could potentially delay construction. Ameresco will have responsibility
for maintaining compliance with the permits through the construction period and the contract
performance period.

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	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

Table 3.1: Environmental Permits & Documents

	 	 	 	 	 	 	 
	 	 	 	 	Completion Date/	 	 
	Permit/Document	 	 	 	Expected Issuance	 	 
	(responsible for	 	 	 	(responsible for	 	 
	permit)	 	Status	 	approval)	 	Schedule Impact
	Site Use Permit (M&O)

	 	Site Use Permit
approved in October
2007, revision will
be submitted to
include river water
routing, outfall
routing and
electrical feeder
routing.
	 	Initial Site Use
Permit Approved,
Revision approved in
June 2008.
(SRS)
	 	Required for Construction & Operation
	 
	 	 	 	 	 	 
	Power Services
Utilization
Permit(s) (Ameresco)

	 	PSUP to be
submitted upon
approval of IFC
drawings.
	 	Approval by end of 2009
(M&O)
	 	Approval before
operation
	 
	 	 	 	 	 	 
	Site Clearance
Permit (M&O)

	 	 	 	Approval by SRS
	 	Approval before
start of
construction work.
	 
	 	 	 	 	 	 
	Environmental
Assessment
(Ameresco/DOE SRS)

	 	Finalizing Draft,
currently out for
public comment
	 	Issuance of Findings
of No Significant
Impact (FONSI)
received in July 2008
	 	Prior to process
discharge to
outfall (operation
of plant)
	 
	 	 	 	 	 	 
	Construction Air
Permit (Ameresco)

	 	Submitted in
February 2008 to
SCDHEC
	 	Approval received in
November 2008
(SCDHEC)
	 	Required before
Construction Start
or Issue of Notice
to Start
Construction by
Government
	 
	 	 	 	 	 	 
	Operating Air Permit
(Ameresco)

	 	To be submitted 180
days after plant
commissioning
	 	(SCDHEC)
	 	Required within 180
days of plant
commissioning
	 
	 	 	 	 	 	 
	NPDES 2D Permit
(National Pollutant
Discharge
Elimination System)
(Ameresco/M&O)

	 	Resubmitted April
11, 2008 to M&O to
submit to SCDHEC as
modification to
site permit
	 	Draft permit issued in
March of 2009
(SCDHEC) with June
2009 being likely the
permit issue date
	 	Prior to process
discharge to
outfall (operation
of plant)
	 
	 	 	 	 	 	 
	401 Water Quality
Certification
(Ameresco)

	 	This permit
application is
submitted
simultaneously with
the Section 404
permit,
	 	Expected 120 days from
submittal of permit
(SCDHEC)
	 	Prior to operation
of plant
	 
	 	 	 	 	 	 
	Wetlands Section 404
Permit
(Ameresco/M&O)

	 	To be submitted by
June 2009
	 	Expected 120 days from
submittal of permit
(US Army Corps of
Engineers)
	 	Prior to operation
of plant

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	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
	Page 53
	 	Contract DE-AM36-02NT41457

Table 3.1: Environmental Permits & Documents

	 	 	 	 	 	 	 
	 	 	 	 	Completion Date/	 	 
	Permit/Document	 	 	 	Expected Issuance	 	 
	(responsible for	 	 	 	(responsible for	 	 
	permit)	 	Status	 	approval)	 	Schedule Impact
	SC R.19-450
Construction in
Navigable Waters
Permit (Ameresco)

	 	This permit
application is
submitted
simultaneously with
the Section 404
permit
	 	Expected 120 days from
submittal of permit
(SCDHEC)
	 	Prior to operation
of plant
	 
	 	 	 	 	 	 
	Industrial
Wastewater Treatment
Permit for oil
separator,
neutralization tank
and for retention
pond (Ameresco)

	 	To be submitted
following the
NPDES permit
modification
approval
	 	Expected by April of
2010
(SCDHEC)
	 	Prior to operation
of plant
	 
	 	 	 	 	 	 
	Notice of Intent for
Storm Water
Discharges from
Large & Small
Construction
Activities
(Ameresco)

	 	To be submitted by
June 2009
	 	M&O ESS Review &

Approval within 30
	 	Prior to
construction of
start of any site
work activities
	 
	 	 	 	 	 	 
	Storm Water
Pollution Prevention
Plan Including Soil
& Erosion Control
(Ameresco)

	 	To be submitted
with NOI for Storm
water Discharges
from Large/Small
Construction
Activities
	 	See Above
	 	Prior to
construction of
start of any site
work activities
	 
	 	 	 	 	 	 
	Grading Permit Application (Ameresco)

	 	To be submitted with NOI for Storm water Discharges from Large/Small Construction Activities
	 	M&O ESS approval

expected within 30

days
	 	Prior to
construction of
start of any site
work activities
	 
	 	 	 	 	 	 
	Construction Permit 

for Domestic Water 

Tie-in, Permit 1970

(Ameresco)

	 	To be submitted by
December 2009
	 	M&O ESS approval

expected within 30

days (M&O ESS acting

authority)
	 	Prior to
construction of
water tie-in &
inspection/approval
required prior to
operation of new
line
	 
	 	 	 	 	 	 
	Construction Permit for Sanitary Sewer Connection, Permit 1970 (Ameresco) 
	 	To be submitted by
December 2009
	 	M&O ESS approval expected within 30 days (M&O ESS acting authority) 	 	Prior to
construction of
sanitary sewer
tie-in

Additional information is provided below for major permits and for the NEPA compliance.

Construction & Operating Air Permit

The equipment in both ECMs are permitted under one new construction air permit and will be under
the Ameresco permit rather than site permit. Ameresco will be responsible for the air permit and
for future air permit renewals throughout the contract term. The following table shows the
potential air emissions

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	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

of the proposed facility for the criteria air pollutants at expected load and at plant capacity.
Annual potential air emissions are typically calculated based on the potential to emit, which is
defined as the emissions for continuous operation at maximum system capacity. The maximum capacity
would be if the boilers are operated at the full load of 120,000 lbs/hr for 8,760 hours. The
controlled emission rates are based on vendor supplied data for the technology proposed in previous
section.

Table 3.2: Annual Emissions Summary for Biomass Cogeneration Facility

	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	Annual Potential Emissions
	 	 	Controlled Emission Rate	 	Actual/Capacity
	Pollutant	 	[lb/MBtu]	[tons/yr]
	Nitrogen Oxides
	 	0.15 (with SCNR)	 	 	227/295	 
	 
	 	 	 	 	 	 	 	 
	Carbon Monoxide
	 	 	0.13	 	 	 	137/195	 
	 
	 	 	 	 	 	 	 	 
	Volatile Organic Compounds
(VOCs)
	 	 	0.15	 	 	 	26/31	 
	 
	 	 	 	 	 	 	 	 
	Particulate Matter Total
	 	 	0.023	 	 	 	35/42	 
	 
	 	 	 	 	 	 	 	 
	Particulate Matter 10
	 	 	0.0203	 	 	 	31/37	 
	 
	 	 	 	 	 	 	 	 
	Sulfur Dioxides
	 	0.025/0.2 with BDF fuel	 	 	46/143	 
	 
	 	 	 	 	 	 	 	 

Table 3.3: Annual Emissions Summary for K&L Heating Plants

	 	 	 	 	 	 	 	 	 
	 	 	Controlled Emission Rate	 	Annual Potential Emissions
	Pollutant	 	[lb/MBtu]	 	[tons/yr]
	Nitrogen Oxides
	 	 	0.219	 	 	 	15	 
	 
	 	 	 	 	 	 	 	 
	Carbon Monoxide
	 	 	0.6	 	 	 	25	 
	 
	 	 	 	 	 	 	 	 
	VOCs
	 	 	0.0128	 	 	 	1	 
	 
	 	 	 	 	 	 	 	 
	Particulate Matter Total
	 	0.2 (with multiclone)	 	 	9	 
	 
	 	 	 	 	 	 	 	 
	Particulate Matter 10
	 	0.119 (with multiclone)	 	 	6	 
	 
	 	 	 	 	 	 	 	 
	Sulfur Dioxides
	 	 	0.025	 	 	 	1	 

The construction air permit was issued in November of this year (2008).

NPDES Permit

The proposed outfall for ECM 1 will be included as part of the SRS NPDES Permit. The modification
to site permit was submitted to the site for approval this past month; it is expected to be
incorporated into the Site permit by March 2009. For ECM 2, the K Area boiler blowdown will
discharge into the K Area Ash Basin, as opposed to being discharged to an NPDES outfall. The NPDES
outfall L-07 was modified to include boiler blowdown discharges for the L Area Biomass Heating
Plant. As part of the Memorandum of Understanding/Memorandum of Agreement (MOU/MOA) between
Ameresco and M&O Contractor, language will be incorporated to require Ameresco to retain
responsibility for compliance of the cogeneration facility outfall and for the K and L Area heating
plant effluents.

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	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

Storm Water Management Permit

The storm water management prevention plan is currently being developed. Once this plan is
submitted, the permit application will be submitted to the M&O Contractor staff for approval. It
is expected it will be approved within 30 days of submittal.

NEPA

Under the National Environmental Policy Act (NEPA), any modification to a federal facility or site
requires determination of the environmental impact of the proposed change or new process. This
requires issuance of a CATEX (categorical exclusion), development of an environmental assessment
(EA) to determine finding of no significant impact (FONSI), or development of an environmental
impact statement. During the DES phase, the EA was developed to include both proposed ECMs. The
document has been placed for public review. The FONSI was issued in July of 2008.

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	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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4.0 ECM PERFORMANCE MEASUREMENT

4.1 Overview of Proposed Annual Savings

Implementation of the proposed ECMs will result in an estimated annual savings of
approximately $34 million. Savings estimates are detailed in DO Schedule 4 in Section 6.0.

4.2 M&V Plan Executive Summary

Measurement and Verification (M&V) options include A, B, C, and D as detailed in M&V
Guidelines of the International Performance Measurement and Verification Protocol (IPMVP).

Table 4.1: M&V Plan Summary

	 	 	 	 	 	 	 
	ECM

 No.	 	ECM Description	 

	M&V Option
 Used*	 	Summary of M&V Plan
	ECM 1

	 	Biomass Cogeneration

Facility
	 	B
	 	Equipment and
system performance
factors
continuously
measured. Steam
produced from the
boilers will be
measured and
totaled for each
performance period
year. Fuel Usage
will be recorded.
Power exported to
the site will also
be measured and
recorded to
determine annual
green power export.
	 
	 	 	 	 	 	 
	ECM 2

	 	K & L Area Heating Plants
	 	B
	 	Equipment and
system performance
factors
continuously
measured. Steam
produced from the
boilers will be
measured and
totaled for each
performance period
year.

 

			
	*	 	M&V options include A, B, C, and D. Guidelines include M&V Guidelines: Measurement & Verification
for Federal Energy Projects, Version 2.2; and International Performance Measurement & Verification
Protocol (IPMVP), Volume I, March 2002, available at
www.eere.energy.gov/femp/financing/superespcs_mvresources.cfm.

Annually, Ameresco will complete an M&V report for the project following a visit to the site
and an analysis of system performance. During the annual site visit, Ameresco staff will collect
the monthly performance/operational data, determine the actual fuel use and costs, and then provide
report of the output of each of the sites. Further, monthly reports will be made available to SRS
which include total steam production from each system and fuel usage. Monthly reports will also
include electrical production parameters in addition to steam.

As stated in the individual ECM description sections, annual savings will be based on the avoided
baseline energy and operations and maintenance costs for the existing plants. Therefore, the
annual savings amount is pre-determined for each year of the contract term and will only change
with annual escalation or a mutually agreed upon baseline adjustment, as the existing plants will
no longer operate once the new biomass plants become operational. The annual avoided baseline
energy and operations and

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	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

maintenance costs for the existing plants are deemed to have been met upon acceptance of the ECMs
by the Government.

Annual performance requirements are satisfied if, for ECM 1 the ASG is met, and if for ECM 2 each
of the heating plants is operated during the heating season as required to meet the Availability
Guarantee.

If Ameresco is able to produce more steam than the ASG in any given year from the cogeneration
plant, the Government may receive such additional steam for power generation or for thermal use.
If the Government requires and Ameresco is able to produce more than 33,300 klbs in any given year
from the total of both the K and L Area heating plants, the Government may receive such excess
steam for additional thermal use. To the extent the actual steam production exceeds the ASG, the
Government will compensate Ameresco for the additional fuel consumption as proposed pursuant to
Section 1.3.1.2.

4.3 Whole Project Data / Global Assumptions

4.3.1 Risk and Responsibility

Ameresco will be responsible for project construction including the installation, testing, and
commissioning of the equipment to deliver a complete and usable facility. Subsequent to
construction, Ameresco will be responsible for ongoing operations and maintenance of the equipment
installed under ECM 1 and ECM 2. Additionally, Ameresco will provide annual M&V reconciliation
services and an annual M&V report which will include documentation of infrastructure and material
condition, and a summary of equipment performance for the previous performance period.

The risk and responsibility of the Measurement and Verification activities for this project are
addressed in the Risk/Responsibility Matrix in Section 5.4 of this proposal.

4.3.2 Energy, Water, and Operations and Maintenance (O&M) Rate Data

Utility Rates

The energy costs (rates) used to develop the baseline annual cost for ECMs 1 and 2 were provided by
SRS based on historical costs. Annual savings were calculated using the current unit cost and for
coal and fuel oil and the baseline consumption data as described in Sections 1.2.7 and 2.2.7.
Post-ECM implementation non fuel utility costs required for operation of the cogeneration facility
and of the heating plants were factored into the savings at the following previously agreed upon
unit costs as shown in the following table:

Table 4.2: Utility Cost for ECM (Post)

	 	 	 	 	 
	Utility	 	Unit Costs
	Electricity
	 	$0.093 / kWh
	 
	 	 	 	 
	River Water
	 	$0.69 / k-gallon

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	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 58
	 	Contract DE-AM36-02NT41457

Table 4.2: Utility Cost for ECM (Post)

	 	 	 	 	 
	Utility	 	Unit Costs
	Domestic Water
	 	$9.42 / k-gallon
	 
	 	 	 	 
	Sanitary Waste Treatment
	 	$7.27 / k-gallon

Performance Period Rate Adjustment Factors

For both ECMs, the annual energy rates used for savings calculations were adjusted using the latest
escalation factors available from the 2008 National Institute of Standards & Technology (NIST).
The applicable NIST escalation rates are shown in Table 4.3 below. O&M cost savings and the
performance period O&M cost use an annual escalation factor of 3%.

Table 4.3: NIST Escalation Rates

	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	NIST Fuel Oil	 	 
	 	 	NIST Electrical	 	NIST Coal 	 	Escalation	 	O&M Escalation 
	Year	 	Escalation   Rates	 	Escalation Rates	 	 Rates	 	 Rates
	2012

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2013

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2014

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2015

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2016

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2017

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2018

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2019

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2020

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2021

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2022

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2023

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2024

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2025

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2026

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2027

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2028

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2029

	 	[**]
	 	[**]
	 	[**]
	 	[**]
	2030

	 	[**]
	 	[**]
	 	[**]
	 	[**]

4.3.3 Schedule & Reporting for Verification Activities

The modified BAMF Super Energy Savings Performance Contract (ESPC) requires Ameresco to submit
to the Government a post-installation report, and thereafter, an annual M&V report documenting
equipment performance. Ameresco will follow the Federal Energy Management Program (FEMP)
guidelines in generating these reports. The post-installation report will be submitted to the
Government within 60 days following notification of an ECM’s substantial completion and beneficial
use as given by

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	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

Ameresco. The performance period report will be submitted each year within 120 days following the
anniversary date of the ECMs substantial completion date.

4.3.4 Status of Utility Company Incentives

There are no known incentives through the utility company for any of the ECMs in this proposal.

4.4 ECM-Specific M&V Plan and Savings Calculation Methods

4.4.1 Overview of ECM Specific M&V Plans

A specific M&V plan based on DOE FEMP Guidelines and the IPMVP for Measurement and
Verification activities during the term of the contract is described for both ECMs in the following
paragraphs.

4.4.1.1 ECM 1: Biomass Cogeneration Facility

M&V Overview

Option B — ECM Isolation will be used for verification of the performance of ECM 1. Option B
focuses [**].

4.4.1.2 ECM 2: Biomass Heating Plants for K& L Areas

M&V Overview

Option B will be used for [**] to the K and L Areas.

4.4.2 Energy and Water Baseline Development

Refer to the summaries of savings calculations in Sections 1.7 and 2.7 of this proposal.

4.4.3 Proposed Energy & Water Savings Calculations and Methodology

Refer to the summaries of savings calculation in Sections 1.7 and 2.7 of this proposal.

4.4.4 Operations and Maintenance Cost Savings

The K Area plant is operated by SRS personnel and the D Area plant operations are
subcontracted by the M&O Contractor to a subsidiary company. Both ECMs will result in the shutdown
of an existing plant and eliminate the operation and maintenance expenses required for these sites.
Therefore, SRS will realize an annual savings of $ [**] of O&M costs for ECM 1 and $[**]
of O&M costs for ECM 2 during the first year of the contract performance period. The O&M cost
savings have been escalated at a previously agreed upon rate of [**]% per year the contract term.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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	 	Contract DE-AM36-02NT41457

5.0 MANAGEMENT APPROACH

5.1 Integrated Management Review Team (IMRT)

Ameresco’s Initial Proposal recommended establishing an Integrated Management Review Team
(IMRT) made up of senior managers from both the Government and Ameresco. While there have been
frequent meetings, conference calls, and project reviews, it is strongly recommended that the IMRT
be activated (in some form) immediately following contract award. As we progress with finalizing
the engineering details and begin mobilizing for construction, the IMRT will be a valuable asset
for promptly resolving any serious challenges that may arise and ensuring that SRS executive level
managers are fully cognizant of project status at all times. It is further recommended the IMRT be
chaired by the Director of the Infrastructure Support & Oversight Division or his designee. The
primary mission of the IMRT will be to assure that appropriate management personnel from each
organization are aware of the project status, informed of key milestones, and if necessary,
involved in securing project approvals.

It is recommended that IMRT membership consists of key personnel from each of the four
organizations participating in the project — DOE SRS, DOE Headquarters, the site M&O contractor
staff, and Ameresco. A proposed IMRT organizational chart, designating team member organizations,
is included as Figure 5.1. The IMRT should be established immediately and convene at least
quarterly throughout the implementation and operations phases to assure senior management is
informed, issues resolved, and decisions are rendered timely.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 61
	 	Contract DE-AM36-02NT41457

Figure 5.1: Integrated Management Review Team

5.2 Ameresco Management Approach

Ameresco will be responsible for the design, construction, and operation of both ECMs as
included in this proposal. This includes the responsibility for the management of design, quality
control, safety, construction, and operation. Ameresco’s management approach is outlined into
following sections and includes the key strategies listed below:

	 	l
	 	 Design in accordance with applicable industry codes and design standards for industrial
heating plants and power plants (Refer to Appendix D for list of standards) and in
accordance with the electrical standards, fire protection standards and stacking lighting
standards provided by Government.
	 
	 	l
	 	 Design documents will be issued to the Government for review and final concurrence
intermittently throughout the first year of the construction period.
	 
	 	l
	 	 Acceptance of changes to the approved design requested by the government is at the
discretion of Ameresco.

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	 	l
	 	 Ameresco is the responsible authority for the job sites of the proposed ECMs. This
includes authority for site management, safety enforcement, document control, quality
control, receipt and acceptance of project deliveries, and construction procurement.
	 
	 	l
	 	 Ameresco will be responsible for document control management including review and
approval of all construction submittals. Ameresco will make electronic copies of major
construction submittals available to government representatives upon request.

Project Implementation Phase (Construction)

Ameresco’s approach to managing the implementation (construction phase) of the proposed measures
will be to assign a fully competent management staff at the construction site and give them the
resources and authority to complete our contract obligations safely, timely, and in a professional
manner. Each member of the on-site management team, headed by the Site Manager, will have the
authority to make project decisions commensurate with their position. Key members of the site
project management team include the Site Manager who will also be the Senior Construction Manager,
Project Construction Manager (engineering subcontractor representative), Job Superintendent, Site
Safety Manager, and Project Documentation Manager. We are currently recruiting, interviewing, and
identifying personnel for most site management positions. However, the Site Safety Manager was
identified early in the DES phase and has been involved with the project for some time. Mr.
Clinton Sandmel will manage the safety program during the construction phase and has interacted
with the SRS Safety Office in completing the project safety analyses and plans, as well as
overseeing the safety efforts of the geotechnical subcontractor. He is an experienced safety
manager and also has experience managing construction safety programs at DOE installations. Mr.
Sandmel and other members of the project management team will be relocated (if not already in the
local area) to the Aiken/Augusta area for the 30 month construction period mitigating travel and
per diem expenses.

Construction subcontractors are being recruited and interviewed from the local area as well as on a
regional and national basis. Ameresco will attempt to maximize the use of local contractor firms
in an effort to support the local economy and mitigate mobilization and travel costs associated
with using subcontractors from outside the local area. Of course, the construction subcontractors
will be key to successful project implementation, and qualifications and price are both
considerations in subcontractor selection. Each subcontractor will provide a project foreman and
safety and quality control personnel. A detailed plan for completing the implementation phase is
included in Section 5.2.6 below.

The site project team will have all the resources necessary to ensure project success available,
including the support of corporate resources from anywhere within the Ameresco organization from
anywhere in North America beginning with the Ameresco corporate staff. While most construction and
project administration activities will be accomplished by the onsite staff, contract
administration, accounting, subcontract administration, and project legal counsel will be
self-performed by division or corporate staff. Technical oversight of engineering, construction
management, and safety will also be accomplished by the corporate resources.

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	 	Savannah River Site
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Operations Phase (Contract Performance Period Services)

Once construction is complete and the Government accepts the project as operational and the
Contract Performance Period begins, the Ameresco staff will shift from implementation to operations
using primarily an onsite staff of Ameresco managers, technicians, and support personnel
supplemented as
necessary by subcontractors and other personnel from within Ameresco’s corporate resources. The
cogeneration facility will operate, and be staffed, 24 hours a days, 7 days a week, 365 days a year
while the K and L Area plants, although not staffed, will operate 24 hours a day, 7 days a week
during the winter heating season.

The Site Operations Manager will lead all facets of ECM operations. This person has not been
determined at this time; however, it is anticipated they will be in place (at the project location)
well before testing and commissioning begins. Key members of the operations staff will be the
Plant Manager, Safety/Environmental Manager, Fuel Procurement Manager, and the Office Manager.
Although we continue to recruit, and have interested candidates, none of the operations staff
managers have been identified at this time. Also, maintenance personnel and plant operators
currently working at the D Area plant will be given an opportunity to join the Ameresco team at the
new cogeneration facility. All site operations and maintenance personnel will reside in the local
community eliminating travel and per diem expenses. Detailed plans for operating the cogeneration
facility and heating plants are included in Section 5.2.7 below.

To the maximum extent practical, project implementation and subsequent plant operations will be
performed under the watchful eye of the skilled and experienced leadership of the onsite management
team; however, the onsite project team will have the full support and backing of additional
corporate resources as necessary.

5.2.1 Ameresco Corporate Management Team

Ameresco’s corporate management team from the ESCO Selection Interview, Initial Proposal, and
Detailed Energy Survey remains intact and will continue to direct, facilitate, and coordinate
Ameresco’s activities into the construction and subsequent operational phase of the biomass ESPC.
Safety and Risk Management have already been added to the corporate team and other additions,
including the Site Manager and Site Operations Manager, will be added at the appropriate time. Mr.
Keith Derrington, Vice President and General Manager will continue as the senior corporate
executive ultimately responsible for assuring success of Ameresco’s Savannah River activities.

An organizational chart depicting the composition of the Ameresco project team is included as
Figure 5.2.

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	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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Figure 5.2: Ameresco’s SRS Biomass Project Team

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	Ameresco Federal Solutions
	 	Savannah River Site
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5.2.2 Program Manager

Mr. Joe Price will continue as Program Manager, although much of the interaction and interface
that he previously facilitated with the DOE and M&O staffs will be transferred to the Site Manager
during construction and ultimately to the Site Operations Manager once the ECMs become operational.
Mr. Price reports to Mr. Derrington and has overall responsibility for Ameresco’s contract
performance and client relationships at SRS. The Program Manager will also lead Ameresco’s
representation to the IMRT, most likely through the implementation phase before passing that
responsibility to the permanent Site Operations Manager, although no decision has been made on that
at this time.

5.2.3 Engineering

Ms. Nicole Bulgarino will continue as Ameresco’s Lead Project Engineer for the cogeneration
facility and the heating plants and will represent the engineering and environmental activities at
the IMRT.
Ms. Bulgarino is responsible for project engineering and design, as well as the subsequent
construction and performance period services. Responsibility for performance period services
including equipment performance issues and annual M&V activities will also fall under purview of
the Engineering Team but will be accomplished by the site operations staff.

5.2.4 Business Operations

Mr. James Koulovatos, Ameresco’s Director of Finance, leads the offices within the business
operations group. Responsibilities of those offices to support the cogeneration facility and
heating plant projects include accounting, contracting, financing, etc. Pending contract award,
Mr. Koulovatos’ staff will manage the development of competitive financing bid packages, work with
3rd party lenders to secure financing for the program, and prepare the final DO
Schedules and Termination Liability Schedule once financing is secured and the interest rate is
locked. Contractual activities include day to day contract administration functions and accounting
will maintain invoicing and accounts receivables ledgers.

5.2.5 Safety and Risk Management

Mr. Kenneth Gross, Ameresco’s Director of Safety and Risk Management, has overall
responsibility for the company’s safety program. Site or project safety personnel will report
directly to Mr. Gross who has been involved with the development of the Worker Health and Safety
Plan (WSHP) to ensure compliance with 10 CRF 851 requirements.

5.2.5.1 Site Safety Management

The Site Safety Manager (SSM) will report to the Director of Safety & Risk Management and is
charged with ensuring the safety of the entire job site. The SSM, Mr. Clinton Sandmel,
participated in development of the WSHP and the associated Job Hazard Analyses (JHA). The SSM is
charged with ensuring that contractor and subcontractor personnel compliance with all applicable
safety regulations. In carrying out site safety duties, the SSM will conduct safety (toolbox)
meetings and inspections and complete the required periodic reports. The SSM will immediately
report unsafe conditions and safety

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	Ameresco Federal Solutions
	 	Savannah River Site
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incidents to the DOE Facility Representatives and the Ameresco Site Manager, Director of Safety and
Risk Management, and the SRS Program Manager.

5.2.6 Construction

As Director of Construction, Mr. Bo Harkness oversees all construction activities within the
federal business unit. The Site Manager, who reports to Mr. Harkness, will be charged with the
day-to-day site management responsibilities during the project implementation phase. Mr. Harkness
will work hand-in-hand with the Program Manager and Lead Engineer to ensure quality construction
completed on schedule and on budget. The Site Manager will also be the on-site point of contact
for SRS/ M&O personnel during the construction phase.

5.2.6.1 Subcontract Management

Onsite construction work will be subcontracted to companies from all parts of the country.
The Director of Construction and Subcontract Administrator will manage all subcontracts, while the
project Site Manager and project Job Superintendent will execute and oversee the subcontracts,
having authority to schedule, inspect, and accept subcontractor work. The Subcontract
Administrator or Director of Construction will respond to any financial or contract management
issues. Invoicing and payments to subcontractors will be handled through standard accounting
procedures and using American Institute of Architects (AIA) contract formats and forms.

5.2.6.2 Construction Management

The Site Manager will be charged with the day-to-day site management responsibilities during
the project construction phase and is tasked with overall responsibility for job site activities.
The Site Manager will also be the on-site point of contact for DOE Facility Representatives and
other SRS/ M&O personnel during the construction phase. Assisted by other Construction Managers
and Job Superintendent personnel, the Site Manager will lead all aspects of project construction
including scheduling, coordination, construction, commissioning, and contract closeout with the
strictest adherence to safety, quality, and cost control procedures.

Project Quality Control (QC) is the responsibility of everyone involved in project activities;
however, ultimate responsibility for the Ameresco QC program rests with the Director of
Construction. Those responsibilities are delegated to the site Quality Control Manager (QCM) who
is tasked to oversee project specific QC activities. The Site Manager or Job Superintendent may be
delegated as the site QCM overseeing the QC activities of all QC personnel, Ameresco and
subcontractors, or a dedicated QCM may be assigned to the project team reporting to the Site
Manager or Job Superintendent.

The site QCM is responsible for individual project quality control. The QCM maintains the Project
Submittal, Testing, and Inspection Logs. The QCM will ensure that project documents (submittals,
shop drawings, reports, etc.) are complete, accurate, and processed in a timely manner. The QCM is
also charged with ensuring testing and inspections are conducted properly and in a manner that will
insure

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	 	Savannah River Site
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accuracy. If necessary, the QCM will contract with specialty/professional testing companies (i.e.
concrete tests and welding x-rays).

Ameresco employs the standard Army Corp of Engineers three-phase quality control process that
includes the preparatory phase, initial phase, and follow-up phase. The preparatory phase is
performed prior to each definable work feature. Actions such as reviewing the drawings and
specifications, checking submittal status, and examining the work area, including a hazard
analysis, are done at this time. The initial phase is performed at the beginning of each definable
work feature. Preliminary work is inspected to insure compliance with the contract, establish the
level of workmanship, and ensure compliance with the safety plan. The follow-up phase is ongoing
during performance of work to ensure compliance with contract requirements, perform testing, and
ensure correction of deficiencies.

5.2.7 Site Operations

Once the ECMs are accepted by the government the project will transition to the site
operations phases, which will continue for the remainder of the delivery order performance term.
It is anticipated the cogeneration facility will be staffed with 20 people whose scope of
responsibilities will include the Biomass Cogeneration Facility and the K and L Area heating
plants.

Ameresco intends to have a Site Operations Manager that will oversee the total operation from fuel
procurement and delivery to plant operations and maintenance. The Site Operations Manager has not
yet been identified; however, we have already received inquiries and resumes from interested
parties.

Ameresco will use reasonable diligence to provide a regular and uninterrupted supply of steam (100%
reliability) to the government-owned distribution systems, but shall not be liable for any damages,
losses, costs, or expenses to the government for failure, suspension, diminution, or other
variations of service occasioned by or in consequence of any cause beyond the control of Ameresco,
including but not limited to acts or omissions of the Government and its agents and contractors,
force majeure conditions e.g. acts of the public enemy, acts of God, fires, floods, earthquakes,
etc., or failure or breakdown of the Government-owned distribution system or end-user facilities.

5.2.7.1 Operations and Maintenance Responsibilities

Ameresco will perform the following operations and maintenance of the equipment and facilities
installed within the Biomass Cogeneration Facility under ECM 1 and for the heating plants installed
in the K and L Areas under ECM 2 for the duration of the contract performance period.

	 	l	 	 Equipment, instrumentation and control systems installed at the Biomass
Cogeneration Facility
	 
	 	l	 	 Equipment, instrumentation and control systems installed at the heating plants
	 
	 	l	 	 Buildings and Infrastructures installed at the Biomass Cogeneration Facility Site
	 
	 	l	 	 Building and Infrastructure installed at the K Area Heating Plant Site
	 
	 	l	 	 Building and Infrastructure installed at the L Area Heating Plant Site
	 
	 	l	 	 Utilities within the Facility and the Heating Plant (as defined in Table 1.2 and Table 2.2)

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	 	Savannah River Site
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	 	l	 	 Access drives and parking lot at the Cogeneration Facility
	 
	 	l	 	 Maintenance of Old Burma Road
	 
	 	l	 	 The existing boiler water treatment equipment and shed at the K Area
	 
	 	l	 	 The existing air compressor at the K Area

The Government, and/or its M&O Contractor will retain responsibility for operating and maintaining
the following items:

	 	l	 	 Utility interconnections as defined in Table 1.2 and Table 2.2
	 
	 	l	 	 Existing utility distribution systems
	 
	 	l	 	 All roads except for facility access roads and the reconstructed Old Burma Road
	 
	 	l	 	 New pump system installed at the River Pump House
	 
	 	l	 	 F Area Substation
	 
	 	l	 	 New D Area electrical feeder
	 
	 	l	 	 L Area capacitors
	 
	 	l	 	 All other existing site infrastructure and systems

The operations and maintenance expenses include the annual costs of labor (Ameresco costs and
service contractor costs from major equipment suppliers) to operate and maintain the plant for both
ECMs and operating costs including chemical costs, fuel oil cost, ash disposal costs, and other
consumables. The operations and maintenance costs are shown on Schedule DO-3 as performance period
expenses.

Operations Overview

The operation of the new plants will be lead by the Ameresco Site Operations Manager or Site
Manager. The Site Manager will oversee operations and maintenance activities to ensure the
following occur:

	 	l	 	 Operate the facility to meet thermal demand of the Savannah River Site in
compliance with applicable local, state and federal permits and regulations.
	 
	 	l	 	 Provide Quality Control for biomass deliveries.
	 
	 	l	 	 Provide a safe work environment for workers and visitors.
	 
	 	l	 	 Perform preventive maintenance in accordance with manufacturer recommendations.
	 
	 	l	 	 Perform major service requirements in accordance with manufacturer recommendations.
	 
	 	l	 	 Maintain professional and positive working relationship with Savannah River
Site personnel, SCDHEC, and surrounding neighbors and community.
	 
	 	l	 	 Provide reports as required for M&V activities to meet plant performance
guarantees.

The Site Operations Manager will [**]

The Safety/Environmental Manager will [**]

The Office Manager will [**]

The Fuel Procurement Manager will [**]

The Plant Manager will [**]

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	 	Savannah River Site
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The following diagram (Figure 5.3) shows the proposed cogeneration facility staffing for operation
of the cogeneration facility and the heating plants.

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	 	Savannah River Site
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Figure 5.3: Proposed Operations Staffing

[**]

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	 	Savannah River Site
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Maintenance Overview

Ameresco will perform the following:

	 	l	 	 Operations including materials and consumables for the cogeneration facility
and heating plants, such as costs for the chemicals, urea, diesel fuel, fuel oil, turbine
filter, lube oil, and ash disposal.
	 
	 	l	 	 Preventive maintenance includes change out of parts, boiler inspection,
boiler cleaning, turbine oil/filter changes, DA tank inspection, pump servicing, grinder
and hogger inspection, instrumentation calibration, engine testing, HVAC servicing,
building upkeep, Old Burma Road repair, and other service as recommended by equipment
suppliers.
	 
	 	l	 	 Unscheduled maintenance includes cost for service and repair not planned on as
part of ongoing maintenance. This mainly consists of contracted service support.

5.2.7.2 Repair & Replacement Responsibilities

The repair and replacement annual expense includes the annual costs expected for the
replacement of materials such as grinder teeth, baghouse filters, sand (bed material) for both
boilers, spare part inventory, and limestone replacement for SOx reduction. These costs will occur
every year regardless of the age of the plant. The repair and replacement costs also include costs
expected to occur for ongoing replacement and repair of boiler in bed tubes, turbine parts, motor
bearings, conveyor belts, and general plant repair fund.

Repair and replacement of the equipment and systems for both ECMs as defined above includes
budgeting and funding an inventory of spare parts, as well as funding and completing minor and
major repairs and equipment replacements. Major repairs and replacements include boiler tubes,
turbine seals, combustor refractory, combustion fans, feedwater pumps, grinders, and augers.
Examples of minor replacements include minor components such as thermocouples, grinder cutters,
instrumentation, motors, motor bearings, filters, chains, and auger components, etc.

5.3 ECM Training

An ongoing O&M Training and Safety Program will be a necessity and training will be provided
to the personnel working at the three sites on a scheduled and recurring basis. Maintaining
training and certification current and in good standing will be required of all personnel. The
training program will also include training with suppliers to ensure the operators are familiar
with the equipment operation and maintenance requirements.

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5.4 Risk/Responsibility Matrix

The following pages contain the ESPC Contract Risk/Responsibility Matrix.

RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	1.    FINANCIAL:

	 	 	 	 
	 
	 	 	 	 
	a.    Interest rates: Neither
the Contractor nor the agency
has significant control over
prevailing interest rates.
During all phases of the
project, interest rates will
change with market conditions.
Higher interest rates will
increase project cost,
financing/project term, or
both. The timing of the
Contract award may impact the
available interest rate and
project cost.

	 	Ameresco has included preliminary
interest rate information in
Schedule DO-3. The interest rate
shown is indicative of the
financial market at the time of
this Revised Final Proposal and is
provided for information purposes
only.

Once locked with Ameresco’s lender,
the interest rate will remain fixed
for the term of the contract,
thereby providing the DOE-SR with
protection against increased
interest charges resulting from a
variable rate.
	 	In 6.10 of the
Revised Final
Proposal, the
DOE-SR agrees,
among other things,
to not withhold,
reduce, or setoff
the “TOTAL DEBT
SERVICE” amount on
Schedule DO-3 in
the event of an
Ameresco default.
The reason for this
is to provide
assurance to
Ameresco’s lender
that its investment
is secure.

The DOE-SR expects
the Ameresco to
obtain the lowest
possible interest
rate and will
competitively seek
financing from
several financial
institutions. The
DOE-SR expects, as
consideration for
6.10, that Ameresco
will obtain a lower
interest rate than
the one indicated
in the Final
Proposal, dated
December 8, 2008.
	 
	 	 	 	 
	b.    Energy prices: Neither the
Contractor nor the agency has
significant control over
actual energy prices. For
calculating savings, the value
of the saved energy may either
be constant, change at a fixed
inflation rate, or float with
market conditions. If the
value changes with the market,
falling energy prices place
the Contractor at risk of
failing to meet cost savings
guarantees. If energy prices
rise, there is a small risk to
the agency that energy

	 	The D Area plant that is being
replaced by the Biomass
Cogeneration Facility is fueled by
coal purchased from SCE&G.
Ameresco proposes to establish the
pre-installation baseline for ECMs
1 and 2 based on the consumption
and cost information provided by
SRS and M&O Ameresco personnel.
The baseline costs are escalated at
2008 published NIST rates for each
year of the performance period.

The energy savings for all ECMs are
calculated based
	 	The rates used to
establish the
energy baseline are
different than what
has been included
in DOE HQ’s
database, Energy
Management System
4. Based on the
unprecedented
increases in coal
costs over the
previous year, the
baseline costs
associated with
coal will come from
SRS’s current
one-year coal
contract for the
D-Area Powerhouse,
which took effect on

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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	       saving
goals might not be met while
the financial goals are. If
the value of saved energy is
fixed (either constant or
escalated), the agency risks
making payments in excess of
actual energy cost savings.
Clarify how future energy
costs will be treated.

	 	on the reduced fuel costs associated
with improved
system efficiencies. To determine
this reduction, the following items
are predetermined for establishing
the pre-installation baseline: the
unit cost of fuel oil and coal, and
the amount of energy produced by
the existing D Area and K Area
plants.

The pre-installation baseline data
used in this proposal consists of
cost and consumption data for a 24
month period as provided by SRS and
M&O personnel for ECM 1, and 5
years of data was used to develop
the baseline for ECM 2. The future
cost of each of these utilities has
been escalated by the applicable
NIST factors for each year
throughout the contract term.

Ameresco proposes the DOE-SR assume
responsibility for the actual unit
cost of utilities (i.e.
electricity, coal, water, etc.)
including any escalation or
de-escalation. If at any time
during the term of this contract,
the ECMs do not create sufficient
savings on an annual basis to fund
the amount due Ameresco for reasons
within SRS’ control or for reasons
related to changes in unit price of
utilities, then SRS will pay
Ameresco as agreed or renegotiate
the payment schedule and term in a
form mutually agreeable to both
parties and Ameresco’s lender such
that the outstanding balance of
contract payments is fully repaid.

Ameresco proposes to assume
responsibility for biomass
procurement and has estimated the
price of biomass based on current
local market conditions escalated
at [**]% per year.
	 	November 1,
2008. Based on
market research,
coal is not
expected to
decrease in cost
based on current
and world demand.
In addition, SRS’s
electrical rates
have also increased
dramatically over
the last two years
based on the
increased costs of
coal and natural
gas that the Site’s
electrical supplier
must recoup through
its electric rates
that have been
approved by the
South Carolina
Public Service
Commission. These
baseline rates will
be escalated in
accordance with
NIST standards.

Throughout the
performance period,
Ameresco will be
supplied utilities
at no cost but the
consumption data
will be metered and
supplied to the
Site’s utility
department to be
included in
calculating the
true cost of
generating steam
and/or electricity
from the new
biomass plants for
inclusion in Site
supplied utilities.

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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	c.    Construction costs: The
Contractor is responsible for
determining construction costs
and defining a budget. In a
fixed-price design/build
Contract, the agency assumes
little responsibility for cost
overruns. However, if
construction estimates are
significantly greater than
originally assumed, the
Contractor may find that the
project or measure is no
longer viable and drop it
before Contract award. In any
design/build Contract, the
agency loses some design
control. Clarify design
standards and the design
approval process (including
changes) and how costs will be
reviewed.

	 	A significant portion of Ameresco’s
business is focused on energy
engineering, design and consulting.
Ameresco staff, complemented by
subcontracted experts, are
developing the ECM designs for this
proposal. Additionally, Ameresco’s
in-house construction management
team has collaborated extensively
with the design team, potential
subcontractors, and equipment
suppliers to assure project
constructability, review budgeted
costs, and provide insight into
procurement options. Having all
these functions involved throughout
the DES Phase substantially lowers
the risk of construction cost
overruns, and ensures a realistic
and balanced approach to innovation
and realism in project design.

To manage the risk associated with
escalating prices for construction
materials and equipment, Ameresco
will hold material and labor
pricing set forth in Schedule DO 2
included herein through May 15,
2009. The proposal acceptance
period may be extended; however,
there may be changes in project
pricing. The parties will share
the risk of construction cost
increases that occur prior to
contract award; however, Ameresco
will assume sole responsibility for
cost increases occurring in normal
market conditions after contract
award as well as responsibility for
managing the risks of such
increases. However, should cost
increases be caused by
extraordinary market conditions,
the parties will negotiate changes
to the construction completion
schedule and/or financial terms of
the contract as mutually agreeable
to both parties.
	 	Upon submittal of
the Revised Final
Proposal, a Cost
Reasonableness
Review of
Ameresco’s
Implementation
Costs will be
performed.
Ameresco shall
submit a breakdown
of the
Implementation
costs with the
Revised Final
Proposal to allow
the DOE-SR to
perform the review.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	 

	 	Design-build will be the means of
project implementation, and the
proposed project will be designed
and constructed to meet industry
and those local SRS standards
identified in this proposal, and
included with the contract award.	 	 
	 
	 	 	 	 
	 

	 	[**].	 	 
	 
	 	 	 	 
	 

	 	The basic contract establishes
maximums for Ameresco mark-ups for
both the implementation and
performance periods. Mark-ups
proposed in this proposal are below
the maximums allowed by the BAMF
Contract. Mark-ups associated with
changes resulting from concealed or
environmental conditions of the
project site, customer requests, or
a change in contract requirements
will be negotiated at the time the
change is incorporated into the
contract delivery order, but shall
never exceed the maximum allowed by
the BAMF Contract.	 	 
	 
	 	 	 	 
	d.    M&V costs: The agency
assumes the financial
responsibility for M&V costs
directly or through the
Contractor. If the agency
wishes to reduce M&V cost, it
may do so by accepting less
rigorous M&V activities with
more uncertainty in the
savings estimates. Clarify
how project savings are being
verified (e.g. equipment
performance, operational
factors, energy use) and the
impact on M&V costs.

	 	Ameresco proposes that M&V Option B
– ECM Isolation be used to verify
the performance of ECM 1 and ECM 2.
Project performance will be
continuously metered and reported
to the DOE-SR on a monthly basis.
The metering equipment installed
for the project, in combination
with the established baseline
energy costs and NIST-based annual
adjustments, will provide
sufficient M&V of project
performance without unnecessarily
increasing project costs. Section
4.4 describes the M&V plan in
detail.
	 	The DOE-SR concurs
with the M&V
approach for the
project.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	 

	 	Performance Period M&V costs are
escalated annually at a fixed rate
of [**]%.	 	 
	 
	 	 	 	 
	e.    Non-Energy Cost Savings:
The agency and the ESCO may
agree that the project will
include savings from recurring
and/or one-time costs. This
may include one-time savings
from avoided expenditures for
projects that were
appropriated but will no
longer be necessary.
Including one-time cost
savings before the money has
been appropriated entails some
risk to the agency. Recurring
savings generally result from
reduced O&M expenses or
reduced water consumption.
These O&M and water savings
must be based on actual
spending reductions. Clarify
sources of non-energy cost
savings and how they will be
verified.

	 	Both proposed ECMs will result in
the shutdown of existing DOE-SR
operated plants eliminating
significant O&M expenses currently
incurred by SRS. The O&M cost
baseline is presented for each ECM
and was developed based on
information, and is collaborative
effort between Ameresco, SRS and
M&O technical personnel.

The annual O&M savings have been
escalated annually at a fixed rate
of [**]%.

NOTE: There will be a significant
reduction in the consumption of
water taken from the Savannah
River, although no cost savings
related to such reduction in water
usage have been included in this
proposal.
	 	The DOE-SR has
provided actual O&M
costs for both the
D-Area Powerhouse
and the K-Area
Package Boilers.
The DOE-SR will
review such costs
included in the
Revised Final
Proposal and, if
acceptable,
provide its
concurrence.
	 
	 	 	 	 
	f.    Delays: Both the
Contractor and the agency can
cause delays. Failure to
implement a viable project in
a timely manner costs the
agency in the form of lost
savings, and can add cost to
the project (e.g.,
construction interest,
remobilization). Clarify
schedule and how delays will
be handled.

	 	Ameresco will fully support the
DOE-SR during the review, approval,
and award of the proposed ECMs to
mitigate potential delays as much
as is within Ameresco’s control.
Further, Ameresco will honor the
pricing proposed herein through May
15, 2009; delays in contract award
beyond that time may result in
increased project cost and will
result in project implementation
delays.

Major milestones for obtaining
project approvals, delivery order
award, and project implementation
are indentified in Table 1.7
herein. Ameresco will provide a
	 	SRS will fully
support Ameresco
during the review,
approval, and award
of the proposed
ECMs to mitigate
potential delays,
and award the
Delivery Order on
schedule. In
addition, DOE and
the M&O Contractor
will work with
Ameresco to
facilitate a smooth
mobilization to the
Site and coordinate
the interfaces for
key support requirements
provided by SRS. Critical interface
requirements should be identified on
Ameresco’s schedule to allow for
adequate up front coordination.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	 

	 	detailed project schedule
subsequent to contract award
reflecting the scheduled completion
date for each major element of ECM
1 and 2. The schedule will be
closely monitored throughout the
construction phase by Ameresco’s
on-site management team as well as
corporate management. Their
proactive involvement will mitigate
the occurrence of delays. Should a
delay occur, Ameresco management
will immediately develop a
mitigation plan, discuss it with
the DOE-SR staff, and then take the
necessary actions to ensure the
project remains on schedule.

Schedule Risks & Mitigation

Schedule Delays

The potential for schedule delays
will be constantly monitored, and
immediate and appropriate
mitigation actions will be taken by
Ameresco management personnel if
necessary. The schedule is being
structured both logically and
realistically to minimize the
potential for delays; however,
should an unavoidable delay occur,
Ameresco will work closely with
DOE-SR engineers to determine the
best course of action and, if
necessary, a revised schedule will
be developed and proposed. The
primary objective of any revision
will be to get the work back on
track without extending the
completion date.

Subcontractor Management

Ameresco has pre-qualified many
firms and will continue to
pre-qualify firms that may be
selected as	 	 

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	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	 

	 	subcontractors.
However, Ameresco will continue to
evaluate qualifications and the
firm’s current workload prior to
executing any subcontracts. If
manpower later becomes an issue,
Ameresco will either direct the
firm to hire additional personnel,
hire additional subcontractors, or
replace the subcontractor.

Ameresco will manage subcontractors
and suppliers through close control
and monitoring of all critical
activities. Monitoring and
controls include the following
procedures: weekly progress
meetings, schedule updates, and
materials management plan.

Late Delivery of Materials/Equipment

In order to protect against late
delivery of material or equipment
and keep the project on schedule,
Ameresco will implement and
maintain a materials management
plan and constantly monitor
production and delivery dates.	 	 
	 
	 	 	 	 
	g.    Major changes in facility:
The agency (or Congress)
controls major changes in
facility use, including
closure. Clarify
responsibilities in the event
of a premature facility
closure, loss of funding, or
other major change.

	 	The SRS is not considered a
candidate for closure at any time
in the foreseeable future. Based
on information provided by SRS
personnel, a build-up in operations
is projected to continue past 2020.
The electrical and steam demand
are projected to change in future
years, but it is assumed (almost
certain) that the site will be a
viable entity throughout the
contract term and well beyond.

The structure of the proposed
project significantly reduces risk
associated with changes at the
site. Ameresco will be producing
steam that will provide two
	 	The DOE-SR concurs
with Ameresco’s
projection of the
longevity of SRS
operations. If a
termination were
necessary, the DOE
Contracting Officer
and Ameresco would
proceed utilizing
the applicable
Federal Acquisition
Regulation (FAR)
and Department of
Energy Acquisition
Regulation (DEAR)
requirements.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	 

	 	benefits to the DOE-SR; steam for
thermal processes and electricity.
Should changes at the facility
result in reduced thermal
requirements, Ameresco will produce
more electricity. The first
priority will be to satisfy the
site’s steam needs. Should there
be excess capacity (delta between
guaranteed steam production and
site steam requirements) the steam
will be processed through a turbine
to produce electricity. The
versatility of the process to
satisfy both thermal and electrical
needs of the site mitigates this
risk.

Ameresco has assessed the potential
for closure of the site and
considers it a minimal risk at this
time. However, if SRS should close
or experience a significant
reduction, then Ameresco will be
responsible for characterizing and
quantifying the impact of the
changes on the project. In a
severe case, though highly
improbable, it may necessitate
either a partial or full
termination for convenience;
however, the contract will include
a Termination Liability Schedule to
facilitate arriving at appropriate
termination costs. If a
termination becomes necessary,
Ameresco would comply with the
applicable Federal Acquisition
Regulation (FAR) and Department of
Energy Acquisition Regulation
(DEAR) requirements.	 	 
	 
	 	 	 	 
	2.    OPERATIONAL:

	 	 	 	 
	 
	 	 	 	 
	a.    Operating hours: The
agency generally has control
over the operating hours.
Increases and decreases in
operating hours can show up as
increases or decreases in
“savings” depending on 

	 	Operating hours of the proposed
cogeneration facility and heating
plants have been pre-determined.
The operating hours of SRS
facilities obtaining service from
the Ameresco plants (i.e., steam
and/or electricity)
	 	The DOE-SR concurs
with this approach
since the ASG will
not be dependent on
facility operating
hours. Excess
steam above the
customer requirements will be

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	       the M&V
method (e.g. operating hours
multiplied by improved
efficiency of equipment vs.
whole building/utility bill
analysis). Clarify whether
operating hours are to be
measured or stipulated and
what the impact will be if
they change. If the operating
hours are stipulated, the
baseline should be carefully
documented and agreed to by
both parties.

	 	were also
determined for purposes of
establishing baseline consumption
data, but will have little to no
impact on the operations of the
proposed ECMs unless increased
operating hours contributes to the
site requiring more steam than
provided by the ASG.

ECM 1, the cogeneration facility
(replacing existing D Area plant)
shall operate 24/7 year round and
ECM 2, the K and L Area plants will
operate 24/7 as necessary over
approximately a four month period
each year to meet building heating
loads. Although operating hours
are pre-determined, steam delivery
requirements will be both
pre-determined and measured.

Over the past two years, SRS’
energy consumption has been
relatively consistent in
conjunction with the operating
hours. Therefore, the energy
baseline and guarantees assume
predetermined operating hours for
the term of the delivery order;
however, Ameresco will guarantee an
annual quantity of steam production
that will not be impacted by
changes to facility operating
hours.

The DOE-SR will control and be
responsible for its increasing or
decreasing facility operating
hours.
	 	dispatched for
electrical
generation.
	 
	 	 	 	 
	b.    Load: Equipment loads can
change over time. The agency
generally has control over
hours of operation,
conditioned floor area,
intensity of use (e.g. changes
in occupancy or level of
automation). Changes in load
can show up as increases or
decreases in “savings”
depending on the M&V

	 	The overall site steam load is
expected to decrease in the out
years of the contract performance
period. Ameresco and DOE-SR
personnel worked closely during the
DES phase to construct a model of
out year steam requirements to
accommodate the decreases. Project
performance calculations are based
on load
	 	The DOE-SR agrees
with Ameresco’s
proposed approach.
Additional steam
requested by the
DOE-SR above the
ASG will be
compensated for at
Ameresco’s
incremental biomass
expense with a
mutually negotiated markup.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	       method.
Clarify whether equipment
loads are to be measured or
stipulated and what the impact
will be if they change. If
the equipment loads are
stipulated, the baseline
should be carefully documented
and agreed to by both parties.

	 	projections shown in Table
1.1, which were provided by site
personnel and are assumed by
Ameresco to be correct. Decreasing
steam requirements will be
accommodated by increasing net
green power generation. Increasing
steam requirements above ASG
(excess production) will be
accommodated up to the maximum
plant capacity. Compensation for
the excess steam production will be
included in the annual cost
adjustment.

It is proposed that the DOE-SR and
Ameresco share the risk of
increased load requirements.
Ameresco will assume responsibility
for providing the steam to meet
increased loads up to the maximum
plant capacity. However, Ameresco
will be compensated for steam
deliveries above the guaranteed
annual production quantities as
provided for by the fuel adjustment
provision found in Section 1.3.1.2
of this proposal.	 	 
	 
	 	 	 	 
	c.    Weather: A number of
energy efficiency measures are
affected by weather. Neither
the Contractor nor the agency
has control over the weather.
Changes in weather can
increase or decrease “savings”
depending on the M&V method
(e.g. equipment run hours
multiplied by efficiency
improvement vs. whole building
utility bill analysis). If
weather is “normalized,”
actual savings could be less
than payments for a given
year, but will average out
over the long run. Clearly
specify how weather
corrections will be performed.

	 	Neither Ameresco nor the DOE-SR has
control over the weather and
changes in weather can increase or
decrease the amount of steam needed
by SRS facilities. However, the
metric for determining whether
Ameresco has satisfied its
performance guarantees are not
weather dependent; therefore,
weather corrections are not be
necessary. Ameresco proposes that
no weather corrections be made as
neither ECM will be significantly
impacted by the weather since the
baseline has been developed from
historical consumption data.

NOTE: Although weather could
impact the amount of steam needed
for heating purposes, that risk has
been
	 	The DOE-SR agrees
with Ameresco’s
proposed approach.

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	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	 

	 	addressed by increased
electrical generation as outlined
in paragraph b above.	 	 
	 
	 	 	 	 
	d.    User participation: Many
energy conservation measures
require user participation to
generate savings (e.g. control
settings). The savings can be
variable and the Contractor
may be unwilling to invest in
these measures. Clarify what
degree of user participation
is needed and utilize
monitoring and training to
mitigate risk. If performance
is stipulated, document and
review assumptions carefully
and consider M & V to confirm
the capacity to save (e.g.
confirm that the controls are
functioning properly).

	 	Ameresco will operate and maintain
the systems proposed under both
ECMs as defined in Section 5.2.7.1.
The ECMs will interconnect with
site utility distribution systems
that will be maintained by the site
M&O Contractor, as is currently the
case. The DOE-SR will be the end
user of the steam produced by the
Ameresco plants. The Government
must accept steam deliveries and
the site M&O contractor must ensure
utility services are available for
the ECMs to be effective. The risk
of either the DOE-SR not accepting
steam deliveries (within the
baseline amounts) or the utility
systems being down over prolonged
period of time is minimal.
	 	The DOE-SR
agrees with
Ameresco’s proposed
approach.
	 
	 	 	 	 
	3.    PERFORMANCE:

	 	 	 	 
	 
	 	 	 	 
	a.    Equipment performance:
Generally the Contractor has
control over the selection of
equipment and is responsible
for its proper installation,
commissioning, and
performance. Generally the
Contractor has responsibility
to demonstrate that the new
improvements meet expected
performance levels including
specified equipment capacity,
standards of service, and
efficiency. Clarify who is
responsible for initial and
long-term performance, how it
will be verified, and what
will be done if performance
does not meet expectations.

	 	Ameresco will retain responsibility
for the performance of the
equipment throughout the term of
the performance period for both
ECMs as defined in Section 5.2.7.1.
Ameresco has experience and is
familiar with the equipment. It
selected the equipment based upon
efficiency, performance level, and
reliability, and in conjunction
with the manufacturer’s service and
performance guarantees.
Performance of the equipment will
be reflected in the annual M&V
documentation provided by Ameresco.
	 	The DOE-SR agrees
with Ameresco’s
proposed approach.
	 
	 	 	 	 
	b.    Operations: Responsibility
for operations is negotiable,
and it can impact performance.
Clarify

	 	Ameresco will retain operations
responsibility and assumes the
risks associated with ECM
operations
	 	The DOE-SR agrees
with the Ameresco’s
proposed approach.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 83
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RISK/RESPONSIBILITY MATRIX

	 	 	 	 	 
	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	       responsibility for
operations, the implications
of equipment control, how
changes in operating
procedures will be handled,
and how proper operations will
be assured.

	 	throughout the contract
term as defined in Section 5.2.7.1.
Proper operations will be assured
by appropriate staffing levels of
the plant by local Ameresco
personnel and/or contracted
employees.

Ameresco site management will
implement and oversee plant
operations to ensure equipment is
operated and maintained to provide
an efficient and safe operation
that satisfies manufacturer and
contract requirements.

Title to the biomass fuel will pass
to the DOE-SR upon delivery to the
plant site. Should the biomass
fuel become damaged or destroyed
due to the fault or negligence of
Ameresco, then Ameresco shall bear
responsibility for replacing such
damaged biomass fuel. Otherwise,
DOE-SRS shall be responsible for
any biomass fuel damaged or
destroyed for any other reason.	 	 
	 
	 	 	 	 
	c.    Preventive Maintenance:
Responsibility for maintenance
is negotiable, and it can
impact performance. Clarify
how long-term preventative
maintenance will be assured,
especially if the party
responsible for long-term
performance is not responsible
for maintenance (e.g.,
Contractor provides
maintenance checklist and
reporting frequency). Clarify
who is responsible for
long-term preventive
maintenance to maintain
operational performance
throughout the Contract term.
Clarify what will be done if
inadequate preventive
maintenance impacts
performance.

	 	Ameresco assumes responsibility for
all maintenance and repairs of the
equipment installed in the new
facility under the contract term as
defined in Section 5.2.7.1.
This includes a preventative
maintenance program, incidental
repairs, and warranty work.
Ameresco will verify performance of
the maintenance on an on-going
basis, with an in-depth review of
the maintenance program conducted
during annual performance
reconciliation. The ongoing costs
of operations and maintenance for
the equipment is included in the
performance period expenses and
escalated annually at [**]% for the
duration of the performance period.
	 	The DOE-SR agrees
with Ameresco’s
proposed approach.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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	RESPONSIBILITY/DESCRIPTION	 	AMERESCO’S PROPOSED APPROACH	 	DOE-SR ASSESSMENT
	d.    Equipment Repair and
Replacement: Responsibility
for repair and replacement of
Contractor-installed equipment
is negotiable; however it is
often tied to project
performance. Clarify who is
responsible for the
replacement of failed
components or equipment
throughout the term of the
Contract. Specifically
address potential impacts on
performance due to equipment
failure. Specify expected
equipment life and warranties
for all installed equipment.
Discuss replacement
responsibility when equipment
life is shorter than the term
of the Contract.

	 	Ameresco will assume responsibility
for the repair and/or replacement
of failed components and equipment
throughout the term of the contract
as specified in Section 5.2.7.2
except for such damaged or
destroyed ECM equipment for which
the DOE-SR self-insures pursuant to
Section 6.5 of the Revised Final
Proposal.
	 	As part of the
Performance Period
expenses, Ameresco
has included, and
is clearly
responsible for,
all Repair &
Replacement
functions. Only
Ameresco-installed
equipment that is
damaged or
destroyed for
reasons beyond the
control and without
the fault or
negligence of
Ameresco, may
result in
consideration as
noted in Section
6.5 of the Revised
Final Proposal.

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	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
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6.0 PROPOSAL PRICING INFORMATION

Schedules DO-1 through DO-5(a) (the “DO–Schedules”) presented at the end of this section
provide the economic and financial details of the proposed project based on SRS making annual debt
service payments at the beginning of each performance period and monthly performance period
expenses.

In addition to price quotes and estimates provided by suppliers and vendors, price estimates were
developed using Ameresco software cost models, historical project cost data, and cost estimating
guides (e.g. RS Means, etc.).

6.1 Interest Rate

Ameresco’s locked interest rate of 8.19% as shown on Schedule DO-3 is based on Moody’s AA
Corporate Index, as published by Bloomberg on May 12, 2009, of 6.14% plus a spread above the Index
of 2.05%.

6.2 Finance Procurement Price

The finance procurement price set forth on Schedule DO-3 consists of the following three
components and will fluctuate until the project interest rate mentioned above is fixed:

	 	a)	 	Performance/Payment Bond — Performance and payment bonds are a requirement
of the Contract. The performance bond is purchased by Ameresco to protect the
Government and the third party lender against Ameresco non-performance during the
implementation period. The performance bond applies only to the installation portion
of the work under this contract and does not apply in any way to energy savings
guarantees, payments or maintenance provisions, except that the performance bond shall
guarantee that the installation will be free of defective materials and workmanship
for a period of twelve (12) months following completion and acceptance of the work.
Ameresco’s lender will require the execution a Dual-Obligee Rider naming such lender
as an additional or dual-obligee under the performance bond.
	 
	 	b)	 	Interest During Construction (“IDC”) – This cost represents the interest
costs accruing to Ameresco during the proposed implementation period. Ameresco’s
DO-Schedules assume a traditional upfront funding of the Total Amount Financed into
an interest bearing escrow account upon award of the contract, Ameresco will be
charged interest on the amount funded at the project interest rate and will net these
interest charges with interest earnings on the escrow account’s remaining principal
balance. Ameresco will receive progress payments

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	Revised Final Proposal — May 11, 2009
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	Ameresco Federal Solutions
	 	Savannah River Site
	Page 86
	 	Contract DE-AM36-02NT41457

	 	 	 	for implementation expenses from the escrow account. In addition to the traditional
escrow funding approach, Ameresco is exploring a delayed funding structure in lieu of
the traditional escrow funding structure proposed herein. Under the delayed funding
structure, Ameresco’s lender will advance progress payments to Ameresco periodically
during the construction period. Interest will begin to accrue only on the progress
payments made to Ameresco and accrued interest will negatively amortize the outstanding
balance. Ameresco believes if it is able to utilize the delayed funding structure it
will provide significant savings on interest during construction.
	 
	 	c)	 	Finance Processing Fee – The finance processing fee represents expenses
Ameresco will incur to finance the contract. Typically, this fee is a combination of
the following applicable expenses: legal fees, origination fees, fees for rating
agencies, rate lock fees to fix the interest rate during the implementation period,
trustee or fiscal agent fees, and any rate buydown costs.

6.3 Sales Tax

Ameresco intends to pursue a sales tax exemption with the South Carolina Department of Revenue
(“SCDOR”) with respect to the ECM equipment pursuant to S.C. Code Ann. section 12-36-2120(29).
This exemption provides the following sales are exempt from sales tax: “tangible personal property
purchased by persons under a written contract with the federal government when the contract
necessitating the purchase provides that title and possession of the property is to transfer from
the contractor to the federal government at the time of purchase or after the time of purchase.
This exemption also applies to purchases of tangible personal property which becomes part of real
or personal property owned by the federal government or, as provided in the written contract, is to
transfer to the federal government. This exemption does not apply to purchases of tangible
personal property used or consumed by the purchaser.” The SCDOR also issued South Carolina Revenue
Ruling No. 04-9, which outlines the requirements for contractors to qualify for the
exemption contained in S.C. Code Ann. section 12-36-2120(29). For the contractor’s purchases to
be exempt from sales tax, the contractor must have a written contract with the federal government
which provides that title and possession of the property is to transfer from the contractor to the
federal government at the time of purchase or after the time of purchase and such title and
possession actually transfers to the federal government in accordance with the contract or the
property becomes part of a real or personal property owned by the federal government or is to
transfer to the federal government.

Ameresco must obtain an exemption certificate issued by the SCDOR to purchase tangible personal
property exempt from sales tax. Ameresco will submit an application (S.C. Form ST-10G) together
with a copy of the executed contract to obtain the required exemption certificate. Due to the fact
that Ameresco will not receive an exemption certificate until after contract award is executed,
Ameresco has included a sales tax reserve in its proposal in the approximate amount of $4,600,000.
Should Ameresco receive an exemption certificate, Ameresco will request that its lender deposit the
sales tax reserve into the PPEF upon the Government’s acceptance of the ECMs. Ameresco proposes to
wait until acceptance

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	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 87
	 	Contract DE-AM36-02NT41457

to fund the PPEF with the sales tax reserve to avoid paying interest on such reserve during the
construction period. To the extent that Ameresco is denied an exemption certificate by the SCDOR,
Ameresco will notify the Government of such determination and the sales tax reserve shall be
dispersed to Ameresco by its lender via progress payments.

6.4 Property Tax

Title to all contractor-installed equipment associated with each ECM shall vest in the
Government. Therefore, the Government is the owner of all contractor-installed equipment for
property tax purposes and Ameresco has not included property taxes in this proposal. In the event
the Government elects not to accept title to the contractor-installed equipment, Ameresco would
need to revise this proposal to include all applicable property taxes.

6.5 Insurance

Ameresco will maintain builder’s risk insurance coverage on all contractor-installed equipment
during the implementation period. Ameresco’s proposal does not include any cost related to
insuring any contractor-installed equipment post-acceptance. Title to all equipment installed by
Ameresco shall be vested with the Government after acceptance by the Government of the commercial
operation of such ECM and the Government will self-insure all such Contractor-installed equipment
throughout the Delivery Order term for the Total Amount Financed as shown on Schedule DO-3. This
acceptance shall not relieve Ameresco’s responsibility for ECM performance. Ameresco will be
responsible for operating and maintaining all ECMs throughout the contract term as set forth
herein. If such Ameresco-installed equipment is damaged or destroyed, for reasons beyond the
control and without the fault or negligence of Ameresco, the Government shall have the option to
(i) terminate the Delivery Order (either in part or in whole) and hold Ameresco harmless for the
savings and performance associated with the damaged or destroyed equipment for the remainder of the
term, (ii) pay Ameresco, by separate contract action to repair or replace the damaged or destroyed
equipment and continue making its scheduled payments to Ameresco, or (iii) repair or replace the
damaged or destroyed equipment at its cost and continue making its scheduled payments to the
Ameresco. If the repair/replacement work is performed by any party other than Ameresco, a
commissioning of the repair/replacement work must be conducted, witnessed and approved by both the
Government and Ameresco. This requirement is necessary for Ameresco to continue to guarantee the
related energy savings as set herein.

6.6 Payment/Term

Ameresco will submit its initial invoice for payment with respect to an ECM upon the earlier
of (i) completion of the ECM and acceptance by the Government or (ii) when the Government has
beneficial use of such ECM. Following the initial invoice submittals by Ameresco, Ameresco will
invoice the Government on or before the first day of April each year thereafter such that the
Government’s annual

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	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 88
	 	Contract DE-AM36-02NT41457

Debt Service payment will be paid annually on or before the first day of May. Performance Period
Expenses will be paid monthly on the first day of each month in an amount equal to one-twelfth
(1/12) of the Total Performance Period Expenses due for each Performance Period.
Submission of or revisions to the Post Installation Completion Report, As-Built drawings, or
O&M Manuals, or delays in providing training that do not affect savings, shall not delay acceptance
with respect to the commencement of making payments to Ameresco, but will be noted as punch list
items and addressed by Ameresco in a timely manner. Ameresco is proposing annual debt service
payments be made at the beginning of each performance period because it reduces the principal
balance the fastest and results in the lowest interest expense to the Government. The annual debt
service period will occur and payment will be due prior to Ameresco’s submission of the applicable
year’s Annual M&V Report. However, any shortfall in Annual Savings set forth in such report will
be adjusted from future performance period payments as provided in Section G.4 of the BAMF
Contract. Payments from the government will be applied first to prompt payment interest, then to
performance period expenses, then to interest and then to principal.

6.7 Cancellation/Termination/Buyout

Schedule DO-5(a) — Termination Liability Schedule is provided with this proposal in addition
to Schedule DO-5. Schedule DO-5(a) provides an amortization of the project’s outstanding principal
balance along with the calculation used to determine the Termination Liability and is provided for
use in the event that the Government prepays or terminates the project for its convenience.
Schedule DO-5(a) represents Ameresco and its third-party lender’s recovery of allowable contract
expenditures, and associated profit, incurred as of the date of termination or buyout and assumes
all payments are received by Ameresco (or its assignee) when due. The column titled “Outstanding
Principal Balance” represents Ameresco’s recovery of costs associated with the installation work in
connection with implementing the ECMs. The column titled “Lender’s Termination Premium” over the
original project cost represents the third-party lender’s immediate recovery of administrative,
placement, legal, and investment banking expenses associated with the original financing as well as
its termination. These financing costs are not represented in the project cost as a line item, but
are built into the interest rate spread and recovered over time as debt service. If Schedule
DO-5(a) only reflected the project costs, Ameresco’s third party lender would fail to recover their
allowable contract expenses and associated profit in the event of a termination or buyout. The
lender’s termination premium is a cost recovery alternative that the third-party lender must rely
on in the event of a termination or buyout in lieu of amortizing fees and costs over time.

In the event of a termination for convenience in whole, cancellation in whole, or prepayment in
whole, the Government acknowledges and agrees that it shall be obligated to pay the specific
Termination Liability amount set forth on Schedule DO-5(a) for the month corresponding to the
effective date the Government intends to make payment to Ameresco. In the event of a termination
for convenience in part, cancellation in part or reduction in requirements in part, the Government
acknowledges and agrees that Ameresco shall apply any such payment made by the Government to the
Outstanding Balance and Lender’s Termination Premium amounts set forth on Schedule DO-5(a)
corresponding to the effective date of such payment in part. Following the application of such
payment in part, the Government will enter into a contract

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 89
	 	Contract DE-AM36-02NT41457

modification to incorporate a revised Schedule DO-5(a) reflecting, at the Government’s option, a
reduction in the total number of payments or reduction in amount per payment over the remaining
term such that, in either case, the Outstanding Principal Balance is fully repaid. In the event of
a prepayment or buydown, the Government acknowledges and agrees that Ameresco shall apply any such
payment made by the Government as set forth in Section 6.8 below.

Any termination for convenience of the Performance Period portion of the contract shall be handled
in accordance with FAR 52.249-2.

6.8 Prepayments/Buydowns

In the event the Government chooses to make prepayments or buydowns during the performance
period of the contract term, with the purpose of reducing the outstanding unamortized balance of
the financing for the ECMs, and thereby reducing the price/payments and overall term of the
contract, the following method shall be used to apply those prepayments to the delivery order
price:

The prepayment amount will be placed by the third-party financier into an account to be identified
in the prepayment modification to the delivery order, to be reinvested at a fixed rate, and at
which rate the amount shall earn and accrue interest, for the shorter of (a) the remaining term of
the delivery order, as revised by delivery order modification of the award Schedules at the time of
any prepayment; or (b) the period up to the date the delivery order may be terminated by the
Government. Determination of the fixed rate at which the prepayment amount shall earn and accrue
interest shall be by mutual agreement of the parties based on then-current reinvestment rates. The
sum of (i) the prepayment amount and (ii) projected accrued interest shall be the total amount
applied against the remaining delivery order payments, as reflected in the task order, in reverse
order of the scheduled contract payments. Thereby, the scheduled term of the contract shall be
reduced, and the payment schedule revised and overall price reduced, as reflected in a revised
schedule incorporated into the contract by modification. A revised schedule will also be provided
and incorporated into the delivery order award by modification. This process may be repeated to
incorporate subsequent prepayments.

6.9 Protection of Financier’s Interest

All cure or show-cause notices or notices of default will be mailed by the Government to
Ameresco’s assignee, as set forth in the Notice of Assignment delivered to the Contracting Officer,
at least 15 days in advance of any termination of this contract for default. The Government will
consider requests by such assignee to extend the applicable cure or show-cause response period so
long as such cure is being diligently pursued.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 90
	 	Contract DE-AM36-02NT41457

6.10 Security Interest in ECM Equipment

During the implementation period and prior to title to the ECM equipment vesting in the
Government, the Government agrees to subordinate any security interest it may have in any Ameresco
installed ECM equipment to Ameresco’s lender, and grants such lender a first priority security
interest in the ECM equipment. Upon the Government’s acceptance of each ECM, Ameresco will cause
its lender to release its security interest in such ECM equipment and to deliver evidence of such
to the Contracting Officer.

6.11 Assignment of Claims

Pursuant to DOE FAR subpart 932.803 Policies, Ameresco proposes to finance the ECMs through an
assignment of the Government’s payments under the contract awarded in connection with this proposal
in compliance with FAR 52.232-23 Assignment of Claims, Alternate I (Apr 1984). Ameresco or its
lender will remit to the Government the required Notice of Assignment together with the Instrument
of Assignment. The Government agrees to acknowledge receipt of such notice and incorporate such
assignment in a contract modification.

6.12 Title to and Responsibility for Contractor-Installed Property

The Government acknowledges that, with respect to the ECMs, the Government is obligated to
accept delivery thereof pursuant to the contract upon satisfaction of the conditions thereto.
After acceptance by the Government of the installed ECMs and vesting of title with the Government
to the equipment installed by Ameresco, the Government agrees that there shall be no withholding,
reduction or setoff by the Government in the payment of the specific amounts as set forth in the
row labeled “TOTAL DEBT SERVICE” on Schedule DO-3 as a result of (i) any termination for default,
in whole or in part, pursuant to FAR Clause 52.249-8 (Default-Fixed Price Supply and Service) by
the Government of the Performance Period (as defined in Modification M005 to Contract No.
DE-AM36-02NT41457, Section J, Attachment 1) portion of the contract, or (ii) any costs assessed
against Ameresco pursuant to FAR Clause 52.246-4 (Inspection of Services-Fixed Price).

In the event of any termination for default, in whole, of the Performance Period portion of the
contract, the Government may elect to, but in no way is obligated or required to, buyout the
Ameresco installed equipment by paying the sum of the columns labeled “Outstanding Principal
Balance” and “Lender’s Termination Premium” on Schedule DO-5(a) for the month corresponding to the
effective date of such termination (the “Buyout Amount”). In the event of such an election by the
Government, the Government agrees that, with respect to the Buyout Amount, there shall be no
withholding, reduction or setoff by the Government in the payment thereof.

In the event of any termination for default, in whole or in part, of the Performance Period portion
of the contract pursuant to FAR Clause 52.249-8 (Default-Fixed Price Supply and Service) or
assessment of costs against Ameresco pursuant to FAR Clause 52.246-4 (Inspection of Services-Fixed
Price), the

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

			
	 	 	 
	Revised Final Proposal — May 11, 2009
	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions
	 	Savannah River Site
	Page 91
	 	Contract DE-AM36-02NT41457

Government reserves the right to exercise any and all of its rights and remedies against Ameresco
(including any and all rights to recover excess reprocurement costs that the Government may incur
as a result of Ameresco’s default and/or Ameresco’s failure to perform the Performance Period
portion of the contract), except for the withholding, reduction or setoff restrictions expressly
provided for herein.

6.13 Construction Milestones

The Government agrees, from time to time during the implementation period, to provide its
written acknowledgement of the satisfaction of certain predetermined construction milestones set
forth on Table 1.7 Project Milestones. Any such acknowledgement by the Government will not
constitute acceptance of the ECM on the part of the Government and will not require the Government
to commence making payments until such ECM is operational as described herein.

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

DO

SCHEDULES

 

 

SCHEDULE DO-1 (Final)

Guaranteed Annual Cost Savings and Annual Contractor Payments

If selected, the Contractor shall complete the installation of all proposed ECMs not later than
34 months after delivery award.

	 	 	 	 	 	 	 	 	 	 	 	 	 
	Delivery Order No.:	 	Contractor Name:	 	 	Project Site:	 
	DE-AT09-09SR22572 dated 15-May-2009	 	Ameresco Federal Solutions	 	 	Savannah River Site	 
	 	 	(a)	 	 	(b)	 	 	(c)	 
	 	 	Initial Estimated	 	 	Proposed Guaranteed	 	 	Annual	 
	Performance	 	Annual	 	 	Annual	 	 	Contractor	 
	Period	 	Cost Savings	 	 	Cost Savings	 	 	Payments	 
	Year	 	$	 	 	$	 	 	$	 
	ZERO (6)
	 		[**]	 	 	 	[**]	 	 		[**]	 
	ONE
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TWO
	 		[**]	 	 	 	[**]	 	 		[**]	 
	THREE
	 		[**]	 	 	 	[**]	 	 		[**]	 
	FOUR
	 		[**]	 	 	 	[**]	 	 		[**]	 
	FIVE
	 		[**]	 	 	 	[**]	 	 		[**]	 
	SIX
	 		[**]	 	 	 	[**]	 	 		[**]	 
	SEVEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	EIGHT
	 		[**]	 	 	 	[**]	 	 		[**]	 
	NINE
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	ELEVEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TWELVE
	 		[**]	 	 	 	[**]	 	 		[**]	 
	THIRTEEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	FOURTEEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	FIFTEEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	SIXTEEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	SEVENTEEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	EIGHTEEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	NINETEEN
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TWENTY
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TWENTY-ONE
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TWENTY-TWO
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TWENTY-THREE
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TWENTY-FOUR
	 		[**]	 	 	 	[**]	 	 		[**]	 
	TWENTY-FIVE
	 		[**]	 	 	 	[**]	 	 		[**]	 
	 
	 	 	 	 	 	 	 	 	 
	TOTALS
	 		[**]	 	 	 	[**]	 	 		[**]	 
	 
	 	 	 	 	 	 	 	 	 

 

			
	(1)	 	The first year DES Proposed Annual Cost Savings shall reflect technical proposal &
engineering estimates as presented in DO-4. above represents a 16 month period (January 2012 to
April 2013) and is calculated by dividing the DO-4 savings by 12 months and then multiplying such
amount by 16 months.
	 
	(2)	 	The Guaranteed Annual Cost Savings are based on the site specific M&V plan.
	 
	(3)	 	The Annual Contractor Payments represent the deliver order price and should be
supported by information submitted in Schedules DO-2 and DO-3.
	 
	(4)	 	The Guaranteed Annual Cost Savings must exceed the Annual Contractor Payments for each
performance period year. 
	 
	(5)	 	Provider escalation rates applied to DES Proposed Annual Cost Savings
in column (a) as follows:

				
	 
	 	(a)	 	Energy Rates — Table S-3; Water Rates — [**]%.
	 
	 	(b)	 	Energy Related O&M Savings — [**]%.

			
	 
	(6)	 	Year Zero Contractor Payment includes $300,000 deposit into the PPEF.

 

 

     

SCHEDULE DO-2

IMPLEMENTATION PRICE BY ECM

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Project Site:	 	Delivery Order No.:	 	 	 	Contractor Name:
	Savannah River Site	 	DE-AT09-09SR22572 dated 15-May-2009	 	 	 	Ameresco Federal Solutions
	C.2.2	 	 	 	 	 	 	 	 	 	 	 	 
	Technology	 	 	 	 	 	 	 	(a)	 	(b)	 	(c) = (a) x (1+b)
	Category	 	ECM	 	 	 	ECM	 	Total Implementation	 	Mark-up	 	 
	Letter	 	No.	 	ECM Description - Title	 	Size	 	Expense	 	%	 	Implementation Price
	 
	 	 	 	 	 	 	 		 	 	 	 	 	 	 	$	—	 
	 
	 	 	 	DES/Proposal Development Costs	 	 	 		[**]	 	 	 	[**]	%	 	$	1,164,800	 
	r
	 	1	 	D Area Biomass Replacement Plant	 	240,000 pph; 20 MW	 		[**]	 	 	 	[**]	%	 	$	137,500,762	 
	r
	 	2	 	K&L Area Biomass Replacement Plant	 	(2) 10,500 pph	 		[**]	 	 	 	[**]	%	 	$	10,507,004	 
	 
	 	 	 	 	 	 	 		[**]	 	 	 	 	 	 	$	149,172,566	 
	Bonded Amount ($)
	 	$                                             149,172,566	 	 	 		 	 	 	 	 	 	 	 	 	 

 

			
	 Notes:	 	 
	 
	1)	 	 Total Implementation Expenses shall include direct costs as specified in the Contract
or in negotiated B Schedules.
	 
	2)	 	Contractor shall propose bonded amount representing the basis of
establishing performance and payment bonds per Section H in IDIQ.
	 
	3)	 	Proposed bonded amount is assumed to include markup applied to ECM
expenses above, unless otherwise specified by Contractor.
	 
	4)	 	Bonded Amount ($) negotiated will be used to establish Performance and
Payment Bond sums per Section H.

 

 

     

SCHEDULE DO-3

Performance Period Cash Flow (PAGE 3)

	 

	Project Site:      Savannah River Site

	Delivery Order No:      DE-AT09-09SR22572 dated 15-May-2009

	Contractor:      Ameresco Federal Solutions

	Delivery Order No:      SRS BAMF Revised Final Proposal 11-May-2009

	 	 	 	 	 

	Project Capitalization
	 	 	 	 
	Total Implementation Price (DO-2 Total)
	 	$	149,172,566	 
	Finance Procurement Price ($)
	 	$	25,003,318	 
	Add: Financed PPEF Deposit (See Note 5)
	 	$	9,200,000	 
	Less: Pre-Performance Period Payments
	 	$	—	 
	TOTAL AMOUNT FINANCED
	 	$	183,375,883	 

	 	 	 	 	 

	Applicable Financial
	 	 	 	 
	Index
	 	Moody’s AA Corporate
	Term (Years)
	 	 	12.0	 
	Index Rate
	 	 	6.14	%
	Added Premium
	 	 	2.05	%
	Project Interest Rate
	 	 	8.19	%

	 	 	 

	Issue Date:
	 	May 12, 2009
	Source:
	 	Bloomberg
	 
	Effective Through:
	 	N/A

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	0	 	1	 	2	 	3	 	4	 	5	 	6	 	7	 	8	 	9	 	10	 	11	 	12	 	13	 	14	 	15	 	16	 	17	 	18	 	19	 	20	 	 
	Term     19 years	 	 	 	 	 	Year 1	 	Year 2	 	Year 3	 	Year 4	 	Year 5	 	Year 6	 	Year 7	 	Year 8	 	Year 9	 	Year 10	 	Year 11	 	Year 12	 	Year 13	 	Year 14	 	Year 15	 	Year 16	 	Year 17	 	Year 18	 	Year 19	 	Year 20	 	Totals
	Annual Cash Flow (Performance Period)
	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 
	Debt Service:
	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 
	Interest ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Principal Repayment ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	TOTAL DEBT SERVICE(a)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	 
	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 
	Performance Period Expenses:
	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 	 			 
	Management/Administration ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Maintenance & Operation ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Repair and Replacement ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Measurement and Verification ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Permits and Licenses ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Insurance ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Property Taxes ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Other — Biomass Fuel ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	SUBTOTAL Performance Period Expenses
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Performance Period Mark-Up — All PPEs other than Biomass at 28%
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Performance Period Mark-Up (%) — Biomass at 22%
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Performance Period Mark-Up ($)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	TOTAL PERFORMANCE PERIOD EXPENSES (b)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	PPEF Deposit — ECM-2 from Year 0 Savings(c)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 
	Total Amount Contractor Payments(a) + (b) + (c)
	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 	 		[**]	 

 

			
	Notes:	 	 
	 
	1)	 	Performance Period Expenses shall include only direct costs.
	 
	2)	 	Contractor shall specify escalation rate applied to performance period expenses or
other sources, in accordance with the IDIQ contract.
	 
	3)	 	If applicable, contractor shall specify escalation rate applied to performance period
expenses: Applicable escalation is [**]%, with the exception of Biomass which is [**]%
	 
	4)	 	Year 0 savings will be applied to Performance Period Expenses for ECM-2 and the PPEF
deposit shown in Year 0 above.
	 
	5)	 	The PPEF amount represents the aggreagate of the following amounts to financed and
deposited into the PPEF:

	 	 	 	 	 

	a) Sales tax reserve (see Section 6.3 of the Final Proposal)
	 	$	4,613,228	 
	b) PPEF Funding Amount upon Acceptance
	 	$	4,586,772	 
	 
	PPEF Deposit from financing proceeds
	 	$	9,200,000	 
	 

 

 

     

SCHEDULE DO-4

First Year Energy and Cost Savings by ECM, Technology Category and Delivery Order

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	Contractor: Ameresco Federal Solutions	 	Project Square Footage (KSF):	 	 	 	 
	 	 	 	 	 	 	Delivery Order No.: DE-AT09-09SR22572 dated 15-May-2009	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	(f)	 	(g)	 	(h)	 	 	 	 	 	 	 	 	 	(k)	 	N/A
	Project Site:	 	 	 	 	 	(a)	 	(b)(1)	 	(b)(2)	 	(c)(1)	 	(c)(2)	 	(d)(1)	 	(d)(2)	 	(e)(1)	 	(e)(2)	 	b1+d1+e1	 	b2+c2+d2+e2	 	Other Energy-	 	 	 	 	 	 	 	 	 	g+h+j	 	 	 	 	 	(m)
	C.2.2	 	 	 	 	 	Project or	 	Electric	 	Electric	 	Electric	 	Electric	 	Fuel	 	Fuel	 	Oher	 	Other	 	Total	 	Total	 	Related and	 	(i)	 	(j)	 	Estimated	 	(l)	 	m=l/k
	Tech	 	Savannah River Site	 	ECM Energy	 	Energy	 	Energy	 	Demand	 	Demand	 	Oil	 	Oil	 	Energy	 	Energy	 	Energy	 	Energy	 	O&M	 	Water	 	Water	 	Annual	 	Implementation	 	Simple
	Category	 	ECM	 	 	 	Baseline	 	Savings	 	Savings	 	Savings	 	Savings	 	Savings	 	Savings	 	Savings	 	Savings	 	Savings	 	Cost Savings	 	Cost Savings	 	Savings	 	Savings	 	Cost Savings	 	Price	 	Payback
	Letter	 	No.	 	Description	 	(MBTU/yr)	 	(kWh/yr)	 	($/yr)	 	(kW/yr)	 	($/yr)	 	(Mbtu/yr)	 	($/yr)	 	(Mbtu/yr)	 	($/yr)	 	(Mbtu/yr)	 	($/yr)	 	($/yr)	 	(k-gal/yr)	 	($/yr)	 	($/yr)	 	$ 	 	(yrs)
	q
	 	 	 	DES/Proposal Development Costs	 	 	 	 	 	 	 	 	 	$	—	 	 	 	—	 	 	$	—	 	 	 	—	 	 	$	—	 	 	 	—	 	 	$	—	 	 	 	—	 	 	$	—	 	 	$	—	 	 	 	—	 	 	 	—	 	 	$	—	 	 	$	1,164,800	 	 	 	N/A	 
	r
	 	1	 	D Area Biomass Replacement Plant	 	 	3,978,008	 	 	 	(55,415,523	)	 	$	(3,941,118	)	 	 	—	 	 	$	—	 	 	 	—	 	 	$	—	 	 	 	3,978,008	 	 	$	24,994,446	 	 	 	3,788,874	 	 	$	21,053,328	 	 	$	12,482,882	 	 	 	(460,671	)	 	 	(355,013	)	 	$	33,181,197	 	 	$	137,500,762	 	 	 	4.14	 
	r
	 	2	 	K&L Area Biomass Replacement Plant	 	 	42,884	 	 	 	(345,600	)	 	$	(35,355	)	 	 	—	 	 	$	—	 	 	 	42,884	 	 	$	593,563	 	 	 	—	 	 	$	—	 	 	 	41,704	 	 	$	558,208	 	 	$	638,970	 	 	 	(4,007	)	 	 	(25,917	)	 	$	1,171,260	 	 	$	10,507,004	 	 	 	8.97	 
	 
	 	 	 	 	 	 	—	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
		 	 	 		 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	TOTAL
	 	 	 	 	 	 	 	 	 	 	(55,761,123	)	 	$	(3,976,474	)	 	 	—	 	 	$	—	 	 	 	42,884	 	 	$	593,563	 	 	 	3,978,008	 	 	$	24,994,446	 	 	 	3,830,579	 	 	$	21,611,535	 	 	$	13,121,852	 	 	 	(464,678	)	 	$	(380,930	)	 	$	34,352,457	 	 	$	149,172,566	 	 	 	4.34	 
		 	 	 		 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 

 

			
	Notes:	 	 
	 
	1)	 	Project Square Footage (in 1000 SF) — Include only building square footage affected
by installed ECMs in project.
	 
	2)	 	For column (a) insert estimated energy baseline by ECM and total project in
MBTU based on M&V approach in technical proposal and DES.
	 
	3)	 	Energy conversion factors for MBTU: MBTU=10^6 BTU; Electricity — 3413
BTU/kWh; Natural Gas — 1031 BTU/100CF; Coal — 12,290 BTU/lb; #2 Oil — 138,700 BTU/gal.
	 
	4)	 	“Other” energy savings in (e)(1) and (e)(2) represent coal savings.

 

 

SCHEDULE DO-5

Annual Cancellation Ceiling Schedule

	 	 	 	 	 	 	 	 	 
	Project Site:	 	Delivery Order No.:	 	Contractor Name:
	Savannah River Site	 	DE-AT09-09SR22572 dated 15-May-2009	 	Ameresco Federal Solutions
	 	 	Outstanding Capital	 	Total Cancellation
	 	 	Investment	 	Ceiling
	 	 	$	 	$
	Installation Acceptance
	 	$	183,375,883	 	 	$	192,544,677	 
	End of Year One
	 	$	173,872,203	 	 	$	182,565,813	 
	End of Year Two
	 	$	169,186,687	 	 	$	177,646,021	 
	End of Year Three
	 	$	163,908,479	 	 	$	172,103,903	 
	End of Year Four
	 	$	157,863,143	 	 	$	165,756,300	 
	End of Year Five
	 	$	150,837,374	 	 	$	158,379,243	 
	End of Year Six
	 	$	142,344,922	 	 	$	149,462,168	 
	End of Year Seven
	 	$	132,506,118	 	 	$	139,131,424	 
	End of Year Eight
	 	$	121,479,677	 	 	$	127,553,661	 
	End of Year Nine
	 	$	108,734,351	 	 	$	114,171,068	 
	End of Year Ten
	 	$	92,487,417	 	 	$	97,111,788	 
	End of Year Eleven
	 	$	74,132,095	 	 	$	77,838,700	 
	End of Year Twelve
	 	$	53,511,954	 	 	$	56,187,552	 
	End of Year Thirteen
	 	$	30,483,995	 	 	$	32,008,195	 
	End of Year Fourteen
	 	$	4,662,037	 	 	$	4,895,139	 
	End of Year Fifteen
	 	$	—	 	 	$	—	 
	End of Year Sixteen
	 	$	—	 	 	$	—	 
	End of Year Seventeen
	 	$	—	 	 	$	—	 
	End of Year Eighteen
	 	$	—	 	 	$	—	 
	End of Year Nineteen
	 	$	—	 	 	$	—	 
	End of Year Twenty
	 	$	—	 	 	$	—	 
	End of Year Twenty-one
	 	$	—	 	 	$	—	 
	End of Year Twenty-two
	 	$	—	 	 	$	—	 
	End of Year Twenty-three
	 	$	—	 	 	$	—	 
	End of Year Twenty-four
	 	$	—	 	 	$	—	 
	End of Year Twenty-five
	 	$	—	 	 	$	—	 

 

			
	(1)	 	Outstanding Capital Investment — Remaining Unamortized principal on Total Amount
Financed.
	 
	(2)	 	In the event of contract cancellation or termination for convenience the Termination
Liability amount set forth on the Termination Liability Schedule will apply for amounts due
Contractor’s lender as set forth in Section 6.7 of Contractor’s Proposal.
	 
	(3)	 	The Contractor has attached a monthly Financing Termination Liability Schedule which must
correspond to the annual amounts submitted above in each year for Outstanding Capital Investment.

 

 

     

SCHEDULE DO-5(a) — TERMINATION LIABILITY SCHEDULE

	 	 	 	 	 

	Termination Premium
	 	 	5.0	%
	Service Period Payments
	 	 	467,331,605	 
	PPEF Deposit — ECMs Savings During Construction
	 	 	300,000	 
	Interest Payments
	 	 	144,023,365	 
	Principal Payments
	 	 	183,375,883	 
	Total Payment
	 	 	795,030,853	 

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Project Site: Savannah River Site	 	Delivery Order No.: DE-AT09-09SR22572 dated 15-May-2009	 	Contractor Name: Ameresco Federal Solutions
	Beginning of	 	Payment Due	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	Lender’s Termination	 	 
	Month	 	Date	 	Government Payment	 	Service Period Expenses	 	PPEF Deposit	 	Debt Service Payment	 	Interest	 	Principal	 	Outstanding Principal Balance	 	Premium	 	Termination Liability
	0
	 	06/01/09	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	1
	 	07/01/09	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	2
	 	08/01/09	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	3
	 	09/01/09	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	4
	 	10/01/09	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	5
	 	11/01/09	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	6
	 	12/01/09	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	7
	 	01/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	8
	 	02/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	9
	 	03/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	10
	 	04/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	11
	 	05/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	12
	 	06/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	13
	 	07/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	14
	 	08/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	15
	 	09/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	16
	 	10/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	17
	 	11/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	18
	 	12/01/10	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	19
	 	01/01/11	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	20
	 	02/01/11	 	 	141,914	 	 	 	91,914	 	 	 	50,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	21
	 	03/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	22
	 	04/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	23
	 	05/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	24
	 	06/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	25
	 	07/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	26
	 	08/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	27
	 	09/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	28
	 	10/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	29
	 	11/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	30
	 	12/01/11	 	 	70,957	 	 	 	45,957	 	 	 	25,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	31
	 	01/01/12	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	32
	 	02/01/12	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	33
	 	03/01/12	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	34
	 	04/01/12	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	183,375,883	 	 	 	9,168,794	 	 	 	192,544,677	 
	35
	 	05/01/12	 	 	31,167,469	 	 	 	6,652,639	 	 	 	—	 	 	 	24,514,830	 	 	 	15,011,150	 	 	 	9,503,680	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	36
	 	06/01/12	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	37
	 	07/01/12	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	38
	 	08/01/12	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	39
	 	09/01/12	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	40
	 	10/01/12	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	41
	 	11/01/12	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	42
	 	12/01/12	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	43
	 	01/01/13	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	44
	 	02/01/13	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	45
	 	03/01/13	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	46
	 	04/01/13	 	 	1,330,528	 	 	 	1,330,528	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	173,872,203	 	 	 	8,693,610	 	 	 	182,565,813	 
	47
	 	05/01/13	 	 	20,307,715	 	 	 	1,389,020	 	 	 	—	 	 	 	18,918,695	 	 	 	14,233,179	 	 	 	4,685,516	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	48
	 	06/01/13	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	49
	 	07/01/13	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	50
	 	08/01/13	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	51
	 	09/01/13	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	52
	 	10/01/13	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	53
	 	11/01/13	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	54
	 	12/01/13	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	55
	 	01/01/14	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	56
	 	02/01/14	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	57
	 	03/01/14	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	58
	 	04/01/14	 	 	1,389,020	 	 	 	1,389,020	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	169,186,687	 	 	 	8,459,334	 	 	 	177,646,021	 
	59
	 	05/01/14	 	 	20,578,026	 	 	 	1,450,196	 	 	 	—	 	 	 	19,127,830	 	 	 	13,849,622	 	 	 	5,278,208	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	60
	 	06/01/14	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	61
	 	07/01/14	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	62
	 	08/01/14	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	63
	 	09/01/14	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	64
	 	10/01/14	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	65
	 	11/01/14	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	66
	 	12/01/14	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	67
	 	01/01/15	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	68
	 	02/01/15	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	69
	 	03/01/15	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	70
	 	04/01/15	 	 	1,450,196	 	 	 	1,450,196	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	163,908,479	 	 	 	8,195,424	 	 	 	172,103,903	 
	71
	 	05/01/15	 	 	20,977,066	 	 	 	1,514,182	 	 	 	—	 	 	 	19,462,884	 	 	 	13,417,548	 	 	 	6,045,336	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	72
	 	06/01/15	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	73
	 	07/01/15	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	74
	 	08/01/15	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	75
	 	09/01/15	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	76
	 	10/01/15	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	77
	 	11/01/15	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	78
	 	12/01/15	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	79
	 	01/01/16	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	80
	 	02/01/16	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	81
	 	03/01/16	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 
	82
	 	04/01/16	 	 	1,514,182	 	 	 	1,514,182	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	157,863,143	 	 	 	7,893,157	 	 	 	165,756,300	 

     Note: Interest will accrue on the Outstanding Principal Balance mothly between each Debt
Service Payment date shown above.

 

 

     

SCHEDULE DO-5(a) — TERMINATION LIABILITY SCHEDULE

	 	 	 	 	 

	Termination Premium
	 	 	5.0	%
	Service Period Payments
	 	 	467,331,605	 
	PPEF Deposit — ECMs Savings During Construction
	 	 	300,000	 
	Interest Payments
	 	 	144,023,365	 
	Principal Payments
	 	 	183,375,883	 
	Total Payment
	 	 	795,030,853	 

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Project Site: Savannah River Site	 	Delivery Order No.: DE-AT09-09SR22572 dated 15-May-2009	 	Contractor Name: Ameresco Federal Solutions
	Beginning of	 	Payment Due	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	Lender’s Termination	 	 
	Month	 	Date	 	Government Payment	 	Service Period Expenses	 	PPEF Deposit	 	Debt Service Payment	 	Interest	 	Principal	 	Outstanding Principal Balance	 	Premium	 	Termination Liability
	83
	 	05/01/16	 	 	21,529,558	 	 	 	1,581,111	 	 	 	—	 	 	 	19,948,446	 	 	 	12,922,677	 	 	 	7,025,769	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	84
	 	06/01/16	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	85
	 	07/01/16	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	86
	 	08/01/16	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	87
	 	09/01/16	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	88
	 	10/01/16	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	89
	 	11/01/16	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	90
	 	12/01/16	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	91
	 	01/01/17	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	92
	 	02/01/17	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	93
	 	03/01/17	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	94
	 	04/01/17	 	 	1,581,111	 	 	 	1,581,111	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	150,837,374	 	 	 	7,541,869	 	 	 	158,379,243	 
	95
	 	05/01/17	 	 	22,491,123	 	 	 	1,651,124	 	 	 	—	 	 	 	20,839,999	 	 	 	12,347,547	 	 	 	8,492,452	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	96
	 	06/01/17	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	97
	 	07/01/17	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	98
	 	08/01/17	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	99
	 	09/01/17	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	100
	 	10/01/17	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	101
	 	11/01/17	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	102
	 	12/01/17	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	103
	 	01/01/18	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	104
	 	02/01/18	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	105
	 	03/01/18	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	106
	 	04/01/18	 	 	1,651,124	 	 	 	1,651,124	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	142,344,922	 	 	 	7,117,246	 	 	 	149,462,168	 
	107
	 	05/01/18	 	 	23,215,526	 	 	 	1,724,367	 	 	 	—	 	 	 	21,491,160	 	 	 	11,652,355	 	 	 	9,838,805	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	108
	 	06/01/18	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	109
	 	07/01/18	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	110
	 	08/01/18	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	111
	 	09/01/18	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	112
	 	10/01/18	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	113
	 	11/01/18	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	114
	 	12/01/18	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	115
	 	01/01/19	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	116
	 	02/01/19	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	117
	 	03/01/19	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	118
	 	04/01/19	 	 	1,724,367	 	 	 	1,724,367	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	132,506,118	 	 	 	6,625,306	 	 	 	139,131,424	 
	119
	 	05/01/19	 	 	23,674,383	 	 	 	1,800,991	 	 	 	—	 	 	 	21,873,391	 	 	 	10,846,951	 	 	 	11,026,440	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	120
	 	06/01/19	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	121
	 	07/01/19	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	122
	 	08/01/19	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	123
	 	09/01/19	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	124
	 	10/01/19	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	125
	 	11/01/19	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	126
	 	12/01/19	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	127
	 	01/01/20	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	128
	 	02/01/20	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	129
	 	03/01/20	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	130
	 	04/01/20	 	 	1,800,991	 	 	 	1,800,991	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	121,479,677	 	 	 	6,073,984	 	 	 	127,553,661	 
	131
	 	05/01/20	 	 	24,570,813	 	 	 	1,881,160	 	 	 	—	 	 	 	22,689,653	 	 	 	9,944,326	 	 	 	12,745,326	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	132
	 	06/01/20	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	133
	 	07/01/20	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	134
	 	08/01/20	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	135
	 	09/01/20	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	136
	 	10/01/20	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	137
	 	11/01/20	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	138
	 	12/01/20	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	139
	 	01/01/21	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	140
	 	02/01/21	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	141
	 	03/01/21	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	142
	 	04/01/21	 	 	1,881,160	 	 	 	1,881,160	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	108,734,351	 	 	 	5,436,718	 	 	 	114,171,068	 
	143
	 	05/01/21	 	 	27,112,968	 	 	 	1,965,040	 	 	 	—	 	 	 	25,147,928	 	 	 	8,900,994	 	 	 	16,246,934	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	144
	 	06/01/21	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	145
	 	07/01/21	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	146
	 	08/01/21	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	147
	 	09/01/21	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	148
	 	10/01/21	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	149
	 	11/01/21	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	150
	 	12/01/21	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	151
	 	01/01/22	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	152
	 	02/01/22	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	153
	 	03/01/22	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	154
	 	04/01/22	 	 	1,965,040	 	 	 	1,965,040	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	92,487,417	 	 	 	4,624,371	 	 	 	97,111,788	 
	155
	 	05/01/22	 	 	27,979,151	 	 	 	2,052,809	 	 	 	—	 	 	 	25,926,342	 	 	 	7,571,020	 	 	 	18,355,322	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	156
	 	06/01/22	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	157
	 	07/01/22	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	158
	 	08/01/22	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	159
	 	09/01/22	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	160
	 	10/01/22	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	161
	 	11/01/22	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	162
	 	12/01/22	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	163
	 	01/01/23	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	164
	 	02/01/23	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	165
	 	03/01/23	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 

     Note: Interest will accrue on the Outstanding Principal Balance mothly between each Debt
Service Payment date shown above.

 

 

     

SCHEDULE DO-5(a) — TERMINATION LIABILITY SCHEDULE

	 	 	 	 	 

	Termination Premium
	 	 	5.0	%
	Service Period Payments
	 	 	467,331,605	 
	PPEF Deposit — ECMs Savings During Construction   
	 	       300,000	 
	Interest Payments
	 	 	144,023,365	 
	Principal Payments
	 	 	183,375,883	 
	Total Payment
	 	 	795,030,853	 

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Project Site: Savannah River Site	 	Delivery Order No.: DE-AT09-09SR22572 dated 15-May-2009	 	Contractor Name: Ameresco Federal Solutions
	Beginning of	 	Payment Due	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	Lender’s Termination	 	 
	Month	 	Date	 	Government Payment	 	Service Period Expenses	 	PPEF Deposit	 	Debt Service Payment	 	Interest	 	Principal	 	Outstanding Principal Balance	 	Premium	 	Termination Liability
	166
	 	04/01/23	 	 	2,052,809	 	 	 	2,052,809	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	74,132,095	 	 	 	3,706,605	 	 	 	77,838,700	 
	167
	 	05/01/23	 	 	28,833,246	 	 	 	2,144,652	 	 	 	—	 	 	 	26,688,594	 	 	 	6,068,453	 	 	 	20,620,141	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	168
	 	06/01/23	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	169
	 	07/01/23	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	170
	 	08/01/23	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	171
	 	09/01/23	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	172
	 	10/01/23	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	173
	 	11/01/23	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	174
	 	12/01/23	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	175
	 	01/01/24	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	176
	 	02/01/24	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	177
	 	03/01/24	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	178
	 	04/01/24	 	 	2,144,652	 	 	 	2,144,652	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	53,511,954	 	 	 	2,675,598	 	 	 	56,187,552	 
	179
	 	05/01/24	 	 	29,649,211	 	 	 	2,240,763	 	 	 	—	 	 	 	27,408,448	 	 	 	4,380,489	 	 	 	23,027,959	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	180
	 	06/01/24	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	181
	 	07/01/24	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	182
	 	08/01/24	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	183
	 	09/01/24	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	184
	 	10/01/24	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	185
	 	11/01/24	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	186
	 	12/01/24	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	187
	 	01/01/25	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	188
	 	02/01/25	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	189
	 	03/01/25	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	190
	 	04/01/25	 	 	2,240,763	 	 	 	2,240,763	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	30,483,995	 	 	 	1,524,200	 	 	 	32,008,195	 
	191
	 	05/01/25	 	 	30,658,724	 	 	 	2,341,347	 	 	 	—	 	 	 	28,317,378	 	 	 	2,495,420	 	 	 	25,821,958	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	192
	 	06/01/25	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	193
	 	07/01/25	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	194
	 	08/01/25	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	195
	 	09/01/25	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	196
	 	10/01/25	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	197
	 	11/01/25	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	198
	 	12/01/25	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	199
	 	01/01/26	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	200
	 	02/01/26	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	201
	 	03/01/26	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	202
	 	04/01/26	 	 	2,341,347	 	 	 	2,341,347	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	4,662,037	 	 	 	233,102	 	 	 	4,895,139	 
	203
	 	05/01/26	 	 	7,490,287	 	 	 	2,446,615	 	 	 	—	 	 	 	5,043,672	 	 	 	381,634	 	 	 	4,662,037	 	 	 	—	 	 	 	—	 	 	 	—	 
	204
	 	06/01/26	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	205
	 	07/01/26	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	206
	 	08/01/26	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	207
	 	09/01/26	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	208
	 	10/01/26	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	209
	 	11/01/26	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	210
	 	12/01/26	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	211
	 	01/01/27	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	212
	 	02/01/27	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	213
	 	03/01/27	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	214
	 	04/01/27	 	 	2,446,615	 	 	 	2,446,615	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	215
	 	05/01/27	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	216
	 	06/01/27	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	217
	 	07/01/27	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	218
	 	08/01/27	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	219
	 	09/01/27	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	220
	 	10/01/27	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	221
	 	11/01/27	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	222
	 	12/01/27	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	223
	 	01/01/28	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	224
	 	02/01/28	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	225
	 	03/01/28	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	226
	 	04/01/28	 	 	2,556,793	 	 	 	2,556,793	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	227
	 	05/01/28	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	228
	 	06/01/28	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	229
	 	07/01/28	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	230
	 	08/01/28	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	231
	 	09/01/28	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	232
	 	10/01/28	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	233
	 	11/01/28	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	234
	 	12/01/28	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	235
	 	01/01/29	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	236
	 	02/01/29	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	237
	 	03/01/29	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	238
	 	04/01/29	 	 	2,672,116	 	 	 	2,672,116	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	239
	 	05/01/29	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	240
	 	06/01/29	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	241
	 	07/01/29	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	242
	 	08/01/29	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	243
	 	09/01/29	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	244
	 	10/01/29	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	245
	 	11/01/29	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	246
	 	12/01/29	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	247
	 	01/01/30	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	248
	 	02/01/30	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 

     Note: Interest will accrue on the Outstanding Principal Balance mothly between each Debt
Service Payment date shown above.

 

 

     

SCHEDULE DO-5(a) — TERMINATION LIABILITY SCHEDULE

	 	 	 	 	 

	Termination Premium
	 	 	5.0	%
	Service Period Payments
	 	 	467,331,605	 
	PPEF Deposit — ECMs Savings During Construction
	 	 	300,000	 
	Interest Payments
	 	 	144,023,365	 
	Principal Payments
	 	 	183,375,883	 
	Total Payment
	 	 	795,030,853	 

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Project Site: Savannah River Site	 	Delivery Order No.: DE-AT09-09SR22572 dated 15-May-2009	 	Contractor Name: Ameresco Federal Solutions
	Beginning of	 	Payment Due	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	Lender’s Termination	 	 
	Month	 	Date	 	Government Payment	 	Service Period Expenses	 	PPEF Deposit	 	Debt Service Payment	 	Interest	 	Principal	 	Outstanding Principal Balance	 	Premium	 	Termination Liability
	249
	 	03/01/30	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	250
	 	04/01/30	 	 	2,792,829	 	 	 	2,792,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	251
	 	05/01/30	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	252
	 	06/01/30	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	253
	 	07/01/30	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	254
	 	08/01/30	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	255
	 	09/01/30	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	256
	 	10/01/30	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	257
	 	11/01/30	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	258
	 	12/01/30	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	259
	 	01/01/31	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	260
	 	02/01/31	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	261
	 	03/01/31	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	262
	 	04/01/31	 	 	2,919,191	 	 	 	2,919,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 

     Note: Interest will accrue on the Outstanding Principal Balance mothly between each Debt
Service Payment date shown above.

 

 

APPENDIX A

A total of 21 pages were
omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment.

 

[**]

 

 

APPENDIX B

A total of 2 pages were omitted and filed separately with the Securities and Exchange Commission
pursuant to a request for confidential treatment.

 

			
	[**] 	 	

 

 

APPENDIX C

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 1

	 	Contract DE-AM36-02NT41457

ECM 1 Equipment List for Biomass Cogeneration Facility

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Acid Regen Skid

	 	520-522-600-001
	 	D27	 	 	 	 
	Acid Storage Tank

	 	520-522-300-001
	 	D27	 	 	 	 
	Air Compressor #1

	 	530-533-100-001
	 	D31	 	 	 	 
	Air Compressor #2

	 	530-533-100-002
	 	D31	 	 	 	 
	Air Dryer Skid #1

	 	530-533-500-001
	 	D31	 	 	 	 
	Air Dryer Skid #2

	 	530-533-500-002
	 	D31	 	 	 	 
	Air Heater #1 Expansion Joint

	 	610-616-200-004
	 	D07	 	 	 	 
	Air Heater #2 Expansion Joint

	 	610-616-200-008
	 	D08	 	 	 	 
	Air Receiver

	 	530-533-400-001
	 	D31	 	 	 	 
	Amine Chemical Skid #1

	 	510-515-200-002
	 	D22
	 	 	 	3 motors
	Amine Chemical Skid #2

	 	510-515-200-003
	 	D22
	 	 	 	2 motors
	Antiscalant Pump

	 	520-522-500-002
	 	D26	 	 	 	 
	Ash Conditioner

	 	460-462-100-001
	 	D13
	 	EPI	 	 
	Ash Conditioner Rotary Valve

	 	460-462-101-001
	 	D13
	 	EPI	 	 
	Ash Exhauster #1

	 	460-462-101-001
	 	D13
	 	EPI	 	 
	Ash Exhauster #1 Filter

	 	460-462-102-001
	 	D13
	 	EPI	 	 
	Ash Exhauster #2

	 	460-462-101-002
	 	D13
	 	EPI	 	 
	Ash Exhauster #2 Filter

	 	460-462-102-002
	 	D13
	 	EPI	 	 
	Ash Silo

	 	460-461-200-001
	 	D13
	 	EPI	 	 
	Ash Silo Aeration Blower

	 	470-471-400-001
	 	D13
	 	EPI	 	 
	Ash Silo Double Dump Valve

	 	460-461-201-001
	 	D13
	 	EPI	 	 
	Ash Silo Emergency Safety Shower

	 	170-176-200-002
	 	D32
	 	EPI	 	 
	Ash Silo Truck Scale

	 	430-431-200-003
	 	D13	 	 	 	 
	Ash Silo VAC Filter

	 	410-414-400-001
	 	D13
	 	EPI	 	 
	Ash Silo Vent Filter

	 	410-414-400-002
	 	D13	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 2

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Ash Silo Vent Filter Fan

	 	410-414-303-001
	 	D13
	 	EPI	 	 
	Baghouse #1

	 	320-322-100-001
	 	D11
	 	EPI	 	 
	Baghouse #1 Expansion Joint

	 	610-616-200-011
	 	D11
	 	EPI	 	 
	Baghouse #2

	 	320-322-100-002
	 	D12
	 	EPI	 	 
	Baghouse #2 Expansion Joint

	 	610-616-200-017
	 	D12
	 	EPI	 	 
	BFB Boiler #1

	 	210-211-100-001
	 	D07
	 	EPI	 	 
	BFB Boiler #1 Air Heater #1

	 	250-252-200-001
	 	D07
	 	EPI	 	 
	BFB Boiler #1 Economizer #1

	 	250-251-100-001
	 	D07
	 	EPI	 	 
	BFB Boiler #2

	 	210-211-100-002
	 	D08
	 	EPI	 	 
	BFB Boiler #2 Air Heater #2

	 	250-252-200-002
	 	D08
	 	EPI	 	 
	BFB Boiler #2 Economizer #2

	 	250-251-100-002
	 	D08
	 	EPI	 	 
	Biofuel Disc Screen

	 	440-441-100-001
	 	D03	 	 	 	 
	Biofuel Hogger

	 	440-442-100-001
	 	D03	 	 	 	 
	Biofuel Metering Bin #1

	 	410-412-100-001
	 	D05
	 	EPI
	 	(VFDs) 6 motors
	Biofuel Metering Bin #2

	 	410-412-100-002
	 	D05
	 	EPI
	 	(VFD’s) 6 motors
	Biofuel Truck Dump #1

	 	430-431-100-001
	 	D03	 	 	 	 
	Biofuel Truck Dump #2

	 	430-431-100-002
	 	D03	 	 	 	 
	Biofuel Truck Dump #3

	 	430-431-100-003
	 	D03	 	 	 	 
	Biofuel Truck Reclaimer #1

	 	430-433-300-001
	 	D03	 	 	 	 
	Biofuel Truck Reclaimer #2

	 	430-433-300-002
	 	D03	 	 	 	 
	Biofuel Truck Reclaimer #3

	 	430-433-300-003
	 	D03	 	 	 	 
	Biofuel Truck Scale #1

	 	430-431-200-001
	 	D03	 	 	 	 
	Biofuel Truck Scale #2

	 	430-431-200-002
	 	D03	 	 	 	 
	Bleach Chemical Pump Skid

	 	510-515-300-001
	 	D22
	 	 	 	2 motors
	Boiler #1 CBD Sample Cooler

	 	510-518-100-009
	 	D32
	 	EPI	 	 
	Boiler #1 Hopper #1

	 	610-611-100-001
	 	D14
	 	EPI	 	 
	Boiler #1 Hopper #2

	 	610-611-100-002
	 	D14
	 	EPI	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 3

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Boiler #1 Hopper #3

	 	610-611-100-003
	 	D14
	 	EPI	 	 
	Boiler #1 Hopper #4

	 	610-611-100-004
	 	D14
	 	EPI	 	 
	Boiler #1 SNCR Distribution Module

	 	340-341-400-001
	 	D21
	 	EPI	 	 
	Boiler #1 SNCR Metering Module Skid

	 	340-341-401-001
	 	D21
	 	EPI	 	 
	Boiler #1 Steam Drum Sample Cooler

	 	510-518-100-002
	 	D32	 	 	 	 
	Boiler #2 CBD Sample Cooler

	 	510-518-100-010
	 	D32	 	 	 	 
	Boiler #2 Hopper #1

	 	610-611-100-005
	 	D14
	 	EPI	 	 
	Boiler #2 Hopper #2

	 	610-611-100-006
	 	D14
	 	EPI	 	 
	Boiler #2 Hopper #3

	 	610-611-100-007
	 	D14
	 	EPI	 	 
	Boiler #2 Hopper #4

	 	610-611-100-008
	 	D14
	 	EPI	 	 
	Boiler #2 SNCR Distribution Module

	 	340-341-400-002
	 	D21
	 	EPI	 	 
	Boiler #2 SNCR Metering Module Skid

	 	340-341-401-002
	 	D21
	 	EPI	 	 
	Boiler #2 Steam Drum Sample Cooler

	 	510-518-100-003
	 	D32	 	 	 	 
	Boiler Drag Chain

	 	430-436-100-001
	 	D05	 	 	 	 
	Boiler Feed Water Pump #1

	 	540-541-100-001
	 	D18
	 	 	 	VFD
	Boiler Feed Water Pump #2

	 	540-541-100-002
	 	D18
	 	 	 	VFD
	Boiler Feed Water Pump #3

	 	540-541-100-003
	 	D18
	 	 	 	VFD
	Boiler Feedwater Heater

	 	530-534-100-001
	 	D18	 	 	 	 
	Bottom Blowdown Separator

	 	530-532-100-001
	 	D33	 	 	 	 
	Brine Tank

	 	520-522-100-001
	 	D24	 	 	 	 
	C.I.P. Tank

	 	520-521-700-001
	 	D26	 	 	 	 
	C.I.P. Tank Pump

	 	520-521-701-001
	 	D26	 	 	 	 
	Carbon Filter #1

	 	510-511-200-001
	 	D25	 	 	 	 
	Carbon Filter #2

	 	510-511-200-002
	 	D25	 	 	 	 
	Carbon Filter #3

	 	510-511-200-003
	 	D25	 	 	 	 
	Caustic Regen Skid

	 	520-522-600-002
	 	D27	 	 	 	 
	Caustic Storage Tank

	 	520-522-200-001
	 	D27	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 4

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Chemical Injection Antiscalant

	 	520-522-400-002
	 	D26	 	 	 	 
	Chemical Injection PH Adjustment

	 	520-522-400-001
	 	D26	 	 	 	 
	Circular Stacker Reclaimer

	 	410-412-400-002
	 	D04
	 	 	 	3 motors
	Condensate Sample Cooler

	 	510-518-100-008
	 	D32	 	 	 	 
	Continuous Blowdown Flash Tank #1

	 	530-532-200-001
	 	D33	 	 	 	 
	Continuous Blowdown Flash Tank #2

	 	530-532-200-002
	 	D33	 	 	 	 
	Control Oil Filter #1

	 	820-823-600-003
	 	D36	 	 	 	 
	Control Oil Filter #2

	 	820-823-600-004
	 	D36	 	 	 	 
	Conveyor #1

	 	430-435-100-001
	 	D03	 	 	 	 
	Conveyor #1 Tramp Metal Electromagnet

	 	430-438-400-001
	 	D03	 	 	 	 
	Conveyor #2

	 	430-435-100-002
	 	D03	 	 	 	 
	Conveyor #2 Diverter Gate #1

	 	430-438-200-001
	 	D03	 	 	 	 
	Conveyor #3

	 	430-435-100-003
	 	D04	 	 	 	 
	Conveyor #4

	 	430-435-100-004
	 	D04	 	 	 	 
	Conveyor #5

	 	430-435-100-005
	 	D04	 	 	 	 
	Conveyor #6

	 	430-435-100-006
	 	D04	 	 	 	 
	Cooling Tower

	 	820-821-100-001
	 	D20	 	 	 	 
	Cooling Tower Fan #1

	 	820-821-300-001
	 	D20
	 	 	 	VFD
	Cooling Tower Fan #1 Expansion Joint

	 	630-636-200-007
	 	D20	 	 	 	 
	Cooling Tower Fan #2

	 	820-821-300-002
	 	D20
	 	 	 	VFD
	Cooling Tower Fan #2 Expansion Joint

	 	630-636-200-008
	 	D20	 	 	 	 
	Cooling Tower Fan #3

	 	820-821-300-003
	 	D20	 	 	 	 
	Cooling Water Pump #1

	 	540-546-100-001
	 	D20
	 	 	 	VFD
	Cooling Water Pump #1 Expansion Joint #1

	 	630-636-200-001
	 	D20	 	 	 	 
	Cooling Water Pump #2

	 	540-546-100-002
	 	D20
	 	 	 	VFD
	Cooling Water Pump #2 Expansion Joint #1

	 	630-636-200-003
	 	D20	 	 	 	 
	Cooling Water Pump #3

	 	540-546-100-003
	 	D20
	 	 	 	VFD

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 5

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Cooling Water Pump #3 Expansion Joint #1

	 	630-636-200-005
	 	D20	 	 	 	 
	Deaerator #1

	 	530-531-200-001
	 	D18	 	 	 	 
	Deaerator #2

	 	530-531-200-002
	 	D19	 	 	 	 
	Deaerator Sample Cooler

	 	510-518-100-004
	 	D32	 	 	 	 
	Electric Heater

	 	340-341-500-001
	 	D21	 	 	 	 
	Emergency Oil Pump

	 	820-823-100-003
	 	D35	 	 	 	 
	Exhaust Fan #1

	 	160-161-300-001
	 	D40	 	 	 	 
	Exhaust Fan #2

	 	160-161-300-002
	 	D40	 	 	 	 
	Exhaust Fan #3

	 	160-161-300-003
	 	D40	 	 	 	 
	Exhaust Fan #4

	 	160-161-300-004
	 	D40	 	 	 	 
	Extraction Vapor Fan

	 	820-823-700-001
	 	D35	 	 	 	 
	FAB Fan #1 Expansion Joint

	 	610-616-200-001
	 	D07
	 	EPI	 	 
	FAB Fan #2 Expansion Joint

	 	610-616-200-005
	 	D08
	 	EPI	 	 
	FGR Fan #1

	 	610-244-100-001
	 	D11
	 	EPI	 	 
	FGR Fan #1 Damper

	 	610-615-700-001
	 	D11
	 	EPI	 	 
	FGR Fan #1 Damper Actuator

	 	610-615-701-001
	 	D11
	 	EPI	 	 
	FGR Fan #1 Damper Expansion Joint

	 	610-616-200-016
	 	D11
	 	EPI	 	 
	FGR Fan #1 Expansion Joint

	 	610-616-200-002
	 	D07
	 	EPI	 	 
	FGR Fan #2

	 	610-244-100-002
	 	D12
	 	EPI	 	 
	FGR Fan #2 Damper

	 	610-615-700-002
	 	D12
	 	EPI	 	 
	FGR Fan #2 Damper Actuator

	 	610-615-701-002
	 	D12
	 	EPI	 	 
	FGR Fan #2 Damper Expansion Joint

	 	610-616-200-022
	 	D12
	 	EPI	 	 
	FGR Fan #2 Expansion Joint

	 	610-616-200-006
	 	D08
	 	EPI	 	 
	Fluidizing Air Booster Fan #1

	 	310-313-100-001
	 	D07
	 	EPI	 	 
	Fluidizing Air Booster Fan #1 Damper

	 	310-313-500-001
	 	D07
	 	EPI	 	 
	Fluidizing Air Booster Fan #1 Damper
Actuator

	 	310-313-501-001
	 	D07
	 	EPI	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 6

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Fluidizing Air Booster Fan #2

	 	310-313-100-002
	 	D08
	 	EPI	 	 
	Fluidizing Air Booster Fan #2 Damper

	 	310-313-500-002
	 	D08
	 	EPI	 	 
	Fluidizing Air Booster Fan #2 Damper
Actuator

	 	310-313-501-002
	 	D08
	 	EPI	 	 
	Fuel Oil Pump #1

	 	520-523-400-001
	 	D41	 	 	 	 
	Fuel Oil Pump #2

	 	520-523-400-002
	 	D41	 	 	 	 
	Fuel Oil Stainer

	 	620-623-400-001
	 	D41	 	 	 	 
	Fuel Oil Storage Tank

	 	520-523-100-001
	 	D41	 	 	 	 
	Generator

	 	810-813-100-001
	 	D36	 	 	 	 
	Heater

	 	820-823-201-001
	 	D35	 	 	 	 
	Hotwell Pump #1

	 	540-542-100-001
	 	D34
	 	 	 	VFD
	Hotwell Pump #2

	 	540-542-100-002
	 	D34
	 	 	 	VFD
	Hotwell Pump Expansion Joint #1

	 	630-636-200-016
	 	D34	 	 	 	 
	Hotwell Pump Expansion Joint #2

	 	630-636-200-017
	 	D34	 	 	 	 
	Hotwell Pump Expansion Joint #3

	 	630-636-200-018
	 	D34	 	 	 	 
	Hotwell Pump Expansion Joint #4

	 	630-636-200-019
	 	D34	 	 	 	 
	Hotwell Sump Pump

	 	540-542-100-001
	 	D34	 	 	 	 
	Hydrazine Chemical Pump Skid

	 	510-515-100-001
	 	D22
	 	 	 	3 motors
	ID Fan #1

	 	310-311-100-001
	 	D11
	 	EPI	 	 
	ID Fan #1 Damper #1

	 	310-311-500-001
	 	D11
	 	EPI	 	 
	ID Fan #1 Damper #1 & 2 Actuator

	 	310-311-501-001
	 	D11
	 	EPI	 	 
	ID Fan #1 Damper #1 Expansion Joint

	 	610-616-200-013
	 	D11
	 	EPI	 	 
	ID Fan #1 Damper #2

	 	310-311-500-002
	 	D11
	 	EPI	 	 
	ID Fan #1 Damper #2 Expansion Joint

	 	610-616-200-014
	 	D11
	 	EPI	 	 
	ID Fan #1 Damper Expansion Joint

	 	610-616-200-012
	 	D11
	 	EPI	 	 
	ID Fan #2

	 	310-311-100-002
	 	D12
	 	EPI	 	 
	ID Fan #2 Damper #1

	 	310-311-500-003
	 	D12
	 	EPI	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 7

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	ID Fan #2 Damper #1 & 2 Actuator

	 	310-311-501-002
	 	D12
	 	EPI	 	 
	ID Fan #2 Damper #1 Expansion Joint

	 	610-616-200-019
	 	D12
	 	EPI	 	 
	ID Fan #2 Damper #2

	 	310-311-500-004
	 	D12
	 	EPI	 	 
	ID Fan #2 Damper #2 Expansion Joint

	 	610-616-200-020
	 	D12
	 	EPI	 	 
	ID Fan #2 Damper Expansion Joint

	 	610-616-200-018
	 	D12
	 	EPI	 	 
	Injector

	 	340-341-600-005
	 	D21	 	 	 	 
	Injector

	 	340-341-600-001
	 	D21	 	 	 	 
	Injector

	 	340-341-600-008
	 	D21	 	 	 	 
	Injector

	 	340-341-600-007
	 	D21	 	 	 	 
	Injector

	 	340-341-600-006
	 	D21	 	 	 	 
	Injector

	 	340-341-600-004
	 	D21	 	 	 	 
	Injector

	 	340-341-600-002
	 	D21	 	 	 	 
	Injector

	 	340-341-600-003
	 	D21	 	 	 	 
	Interstage Storage Tank

	 	520-521-900-001
	 	D26	 	 	 	 
	Lube / Control Oil Tank

	 	820-823-400-001
	 	D35	 	 	 	 
	Lube Oil Filter #1

	 	820-823-600-001
	 	D35	 	 	 	 
	Lube Oil Filter #2

	 	820-823-600-002
	 	D35	 	 	 	 
	Lube Oil Purifier System

	 	820-823-200-001
	 	D35	 	 	 	 
	Main Oil Pump

	 	820-823-100-001
	 	D35	 	 	 	 
	Mist Separator

	 	820-823-800-001
	 	D35	 	 	 	 
	Mixed Bed System Emergency Safety
Shower

	 	170-176-200-003
	 	D32	 	 	 	 
	Mixed Bed Unit #1

	 	510-513-100-001
	 	D27	 	 	 	 
	Mixed Bed Unit #2

	 	510-513-100-002
	 	D27	 	 	 	 
	Multi-media Filter #1

	 	510-511-100-001
	 	D23	 	 	 	 
	Multi-media Filter #2

	 	510-511-100-002
	 	D23	 	 	 	 
	Multi-media Filter #3

	 	510-511-100-003
	 	D23	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 8

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Neutralization Pump #1

	 	520-521-801-001
	 	D30	 	 	 	 
	Neutralization Pump #2

	 	520-521-801-002
	 	D30	 	 	 	 
	Neutralization Tank

	 	520-521-800-001
	 	D30	 	 	 	 
	Oil Cooler #1

	 	820-823-500-001
	 	D35	 	 	 	 
	Oil Cooler #2

	 	820-823-500-002
	 	D35	 	 	 	 
	PFA Fan #1 Expansion Joint

	 	610-616-200-003
	 	D07	 	 	 	 
	PFA Fan #2 Expansion Joint

	 	610-616-200-007
	 	D08	 	 	 	 
	PH Adjustment Pump

	 	520-522-500-001
	 	D26	 	 	 	 
	Phosphate Chemical Pump Skid

	 	510-515-200-001
	 	D22
	 	 	 	3 motors
	Primary Fluidizing Air Fan #1

	 	310-312-100-001
	 	D07
	 	EPI	 	 
	Primary Fluidizing Air Fan #1 Damper

	 	310-312-500-001
	 	D07
	 	EPI	 	 
	Primary Fluidizing Air Fan #1 Damper
Actuator

	 	310-312-501-001
	 	D07
	 	EPI	 	 
	Primary Fluidizing Air Fan #1 SCAH

	 	250-253-100-001
	 	D07
	 	EPI	 	 
	Primary Fluidizing Air Fan #1 Silencer

	 	310-312-600-001
	 	D07
	 	EPI	 	 
	Primary Fluidizing Air Fan #2

	 	310-312-100-002
	 	D08
	 	EPI	 	 
	Primary Fluidizing Air Fan #2 Damper

	 	310-312-500-002
	 	D08
	 	EPI	 	 
	Primary Fluidizing Air Fan #2 Damper
Actuator

	 	310-312-501-002
	 	D08
	 	EPI	 	 
	Primary Fluidizing Air Fan #2 SCAH

	 	250-253-100-002
	 	D08
	 	EPI	 	 
	Primary Fluidizing Air Fan #2 Silencer

	 	310-312-600-002
	 	D08
	 	EPI	 	 
	Primary Superheater #1

	 	210-211-200-001
	 	D15
	 	EPI	 	 
	Primary Superheater #2

	 	210-211-200-002
	 	D16
	 	EPI	 	 
	Process Lift Pump #1

	 	530-532-400-001
	 	D33	 	 	 	 
	Process Lift Pump #2

	 	530-532-400-002
	 	D33	 	 	 	 
	RO Feed Pump #1

	 	510-511-400-001
	 	D26	 	 	 	 
	RO Feed Pump #1 Filter

	 	510-511-401-001
	 	D26	 	 	 	 
	RO Feed Pump #2

	 	510-511-400-002
	 	D26	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 9

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	RO Feed Pump #2 Filter

	 	510-511-401-002
	 	D26	 	 	 	 
	RO Forwarding Pump #1

	 	510-511-400-003
	 	D26	 	 	 	 
	RO Forwarding Pump #2

	 	510-511-400-004
	 	D26	 	 	 	 
	RO System

	 	510-511-300-001
	 	D26	 	 	 	 
	Sample Cooler Emergency Safety Shower

	 	170-176-200-001
	 	D32	 	 	 	 
	Sand Bucket Elevator #1

	 	430-434-100-001
	 	D14	 	 	 	 
	Sand Bucket Elevator #2

	 	430-434-100-002
	 	D14	 	 	 	 
	Sand Drag Chain #1

	 	430-436-100-002
	 	D14	 	 	 	 
	Sand Drag Chain #2

	 	430-436-100-003
	 	D14	 	 	 	 
	Sand Drag Chain #3

	 	430-436-100-004
	 	D14	 	 	 	 
	Sand Drag Chain #4

	 	430-436-100-005
	 	D14	 	 	 	 
	Sand Silo #1

	 	410-411-310-001
	 	D14	 	 	 	 
	Sand Silo #1 Bin Vent Filter

	 	410-414-300-004
	 	D14	 	 	 	 
	Sand Silo #1 Screw Conveyor

	 	420-423-100-003
	 	D14
	 	 	 	VFD
	Sand Silo #1 Vent Filter Fan

	 	410-414-301-001
	 	D14	 	 	 	 
	Sand Silo #2

	 	410-411-310-002
	 	D14	 	 	 	 
	Sand Silo #2 Bin Vent Filter

	 	410-414-300-005
	 	D14	 	 	 	 
	Sand Silo #2 Screw Conveyor

	 	420-423-100-004
	 	D14
	 	 	 	VFD
	Sand Silo #2 Vent Filter Fan

	 	410-414-301-002
	 	D14	 	 	 	 
	Secondary Superheater #1

	 	210-211-200-004
	 	D15	 	 	 	 
	Secondary Superheater #2

	 	210-211-200-003
	 	D16	 	 	 	 
	Stack #1

	 	610-614-100-001
	 	D11	 	 	 	 
	Stack #1 Expansion Joint

	 	610-616-200-015
	 	D11
	 	EPI	 	 
	Stack #2

	 	610-614-100-002
	 	D12
	 	EPI	 	 
	Stack #2 Expansion Joint

	 	610-616-200-021
	 	D12
	 	EPI	 	 
	Burner #1 Boiler #1

	 	240-241-200-002
	 	D06
	 	EPI	 	 
	Start-up Burner #1 Boiler #2

	 	240-241-200-004
	 	D06
	 	EPI
	 	Not shown on P&ID

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 10

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Burner #2 Boiler #1

	 	240-241-200-003
	 	D06
	 	EPI	 	 
	Start-up Burner #2 Boiler #2

	 	240-241-200-005
	 	D06
	 	EPI
	 	Not shown on P&ID
	Steam Turbine

	 	810-811-300-001
	 	D36	 	 	 	 
	Sulphuric Acid Chemical Pump Skid

	 	510-515-300-002
	 	D22
	 	 	 	2 motors
	Supply Fan #1

	 	160-161-200-001
	 	D40	 	 	 	 
	Supply Fan #2

	 	160-161-200-002
	 	D40	 	 	 	 
	Supply Fan #3

	 	160-161-200-003
	 	D40	 	 	 	 
	Supply Fan #4

	 	160-161-200-004
	 	D40	 	 	 	 
	Supply Fan #5

	 	160-161-200-005
	 	D40	 	 	 	 
	Supply Fan #6

	 	160-161-200-006
	 	D40	 	 	 	 
	Supply Fan #7

	 	160-161-200-007
	 	D40	 	 	 	 
	Supply Fan #8

	 	160-161-200-008
	 	D40	 	 	 	 
	Surface Condenser

	 	820-822-100-001
	 	D34	 	 	 	 
	Surface Condenser Expansion Joint #1

	 	630-636-200-011
	 	D34	 	 	 	 
	Surface Condenser Expansion Joint #2

	 	630-636-200-012
	 	D34	 	 	 	 
	Surface Condenser Expansion Joint #3

	 	630-636-200-013
	 	D34	 	 	 	 
	Surface Condenser Expansion Joint #4

	 	630-636-200-014
	 	D34	 	 	 	 
	Surface Condenser Expansion Joint #5

	 	630-636-200-015
	 	D34	 	 	 	 
	TDF Reclaimer

	 	430-433-300-004
	 	D05	 	 	 	 
	Treated Water Storage Tank

	 	520-521-300-001
	 	D28	 	 	 	 
	Treated Water Transfer Pump #1

	 	540-544-100-001
	 	D28	 	 	 	 
	Treated Water Transfer Pump #2

	 	540-544-100-002
	 	D28	 	 	 	 
	Urea Circulation Module

	 	340-341-301-001
	 	D21
	 	EPI	 	 
	Urea Circulation Pump #1

	 	340-341-300-001
	 	D21
	 	EPI	 	 
	Urea Circulation Pump #2

	 	340-341-300-002
	 	D21
	 	EPI	 	 
	Urea Metering Pump #1

	 	340-341-300-003
	 	D21
	 	EPI	 	 
	Urea Metering Pump #2

	 	340-341-300-004
	 	D21
	 	EPI	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 1 Equipment List, Page 11

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	ESI Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Urea Metering Pump #3

	 	340-341-300-005
	 	D21
	 	EPI	 	 
	Urea Metering Pump #4

	 	340-341-300-006
	 	D21
	 	EPI	 	 
	Urea Storage Tank

	 	340-341-200-001
	 	D21
	 	EPI	 	 
	Urea Storage Tank Inlet Expansion Joint

	 	630-636-200-009
	 	D21
	 	EPI	 	 
	Urea Storage Tank Outlet Expansion Joint

	 	630-636-200-010
	 	D21
	 	EPI	 	 
	Urea Tank / Acid / Bleach Emergency
Safety Shower

	 	170-176-200-004
	 	D32
	 	EPI	 	 
	Vacuum Pump #1

	 	820-822-201-001
	 	D34	 	 	 	 
	Vacuum Pump #2

	 	820-822-201-001
	 	D34	 	 	 	 
	Vibrating Feeder #1

	 	320-321-300-001
	 	D14
	 	 	 	2 motors
	Vibrating Feeder #2

	 	320-321-300-002
	 	D14
	 	 	 	2 motors
	Water Booster Pump #1

	 	540-543-100-001
	 	D21	 	 	 	 
	Water Booster Pump #2

	 	540-543-100-002
	 	D21	 	 	 	 
	Water Booster Pump #3

	 	540-543-100-003
	 	D21	 	 	 	 
	Water Booster Pump #4

	 	540-543-100-004
	 	D21	 	 	 	 
	Water Softener #1

	 	510-512-100-001
	 	D24	 	 	 	 
	Water Softener #2

	 	510-512-100-002
	 	D24	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 2 Equipment List, Page 1

	 	Contract DE-AM36-02NT41457

ECM 2 Equipment List for Heating Plants for K&L Areas

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Area ‘K’ Air Accumulator

	 	530-533-400-002
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Air Heater

	 	250-252-200-001
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Amine to Steam Line
Chemical Pump #2

	 	510-515-300-001
	 	D23	 	 	 	 
	Area ‘K’ Air Compressor

	 	530-533-100-001
	 	D05
	 	Existing Air Compressor	 	 
	Area ‘K’ Air Receiver

	 	530-533-400-001
	 	D05
	 	Existing Air Compressor	 	 
	Area ‘K’ BFW Pump #1

	 	540-541-100-001
	 	D11
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ BFW Pump #2

	 	540-541-100-002
	 	D11
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ BFW Sample Cooler

	 	510-518-100-003
	 	D19
	 	Process Power & Equipment
Sales, Inc.	 	 
	Area ‘K’ Biofuel Metering Bin

	 	440-443-200-001
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Blowdown Seperator Tank

	 	530-532-100-001
	 	D21
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Blowdown Sump Pump #1

	 	540-549-300-001
	 	D21	 	 	 	 
	Area ‘K’ Blowdown Sump Pump #2

	 	540-549-300-002
	 	D21	 	 	 	 
	Area ‘K’ Brine Tank

	 	510-512-100-003
	 	D19	 	 	 	 
	Area ‘K’ Building Exhaust Fan

	 	160-161-300-001
	 	D26	 	 	 	 
	Area ‘K’ Building Supply Fan

	 	160-161-200-001
	 	D26	 	 	 	 
	Area ‘K’ CBD Sample Cooler

	 	510-518-100-002
	 	D19
	 	Process Power & Equipment
Sales, Inc.	 	 
	Area ‘K’ DCS of PLC System (BFW)

	 	720-725-100-002	 	 	 	 	 	 
	Area ‘K’ DCS or PLC System (Boiler)

	 	720-725-100-001
	 	 	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Deaerator

	 	530-531-100-001
	 	D11
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Duplex Water Softener A

	 	510-512-100-001
	 	D19	 	 	 	 
	Area ‘K’ Duplex Water Softener B

	 	510-512-100-002
	 	D19	 	 	 	 
	Area ‘K’ Electric Heater #1

	 	160-162-500-001
	 	D26	 	 	 	 
	Area ‘K’ Electric Heater #2

	 	160-162-500-002
	 	D26	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 2 Equipment List, Page 2

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Area ‘K’ Electric Heater #3

	 	160-162-500-003
	 	D26	 	 	 	 
	Area ‘K’ Feeder Magnet

	 	430-438-400-001
	 	D03	 	 	 	 
	Area ‘K’ Fly Ash Multiclone

	 	320-321-100-001
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Fly Ash Reinjection Fan

	 	610-244-100-001
	 	D07
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Fly Ash Rotary Air Valve #1

	 	320-321-200-001
	 	D07
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Fly Ash Rotary Air Valve #2

	 	320-321-200-002
	 	D07
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Fuel Oil Back-Up Burner

	 	240-241-200-001
	 	D15
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Fuel Oil Pump

	 	240-243-100-002
	 	D15
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Fuel Oil Pump #1 (ON HOLD)

	 	HOLD
	 	D13	 	 	 	 
	Area ‘K’ Fuel Oil Pump #2 (ON HOLD)

	 	HOLD
	 	D13	 	 	 	 
	Area ‘K’ Fuel Oil Storage Tank

	 	520-523-100-001
	 	D13	 	 	 	 
	Area ‘K’ Fuel Sizing Screen

	 	440-441-100-001
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Hybrid Boiler

	 	210-213-100-001
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Hydrazine to DA Chemical
Pump #1

	 	510-515-100-001
	 	D23	 	 	 	 
	Area ‘K’ ID Fan

	 	310-311-200-001
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Inclined Drag Chain Conveyor

	 	430-436-100-001
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ MCC/PLC Room A.C.

	 	160-162-300-001
	 	D26	 	 	 	 
	Area ‘K’ Metering Bin Screw Conveyor
#1

	 	430-432-100-001
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Metering Bin Screw Conveyor
#2

	 	430-432-100-002
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Non Return Valve

	 	220-221-100-001
	 	D09
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Oil Burner Fan

	 	310-313-100-001
	 	D15
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Overfire Air Fan

	 	310-314-100-001
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Phosphate to BFW Chemical
Pump #3

	 	510-515-200-001
	 	D23	 	 	 	 
	Area ‘K’ Pit Sump Pump

	 	540-549-300-005
	 	D03	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 2 Equipment List, Page 3

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Area ‘K’ Reciprocating Floor Hydraulic
System

	 	430-438-700-001
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Reciprocating Grate Stoker’

	 	230-231-300-001
	 	D07
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Reclaim Vibratory Feeder

	 	430-432-200-001
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Safety Eyewash & Shower

	 	170-176-200-001
	 	D19	 	 	 	 
	Area ‘K’ Sootblower #1

	 	220-223-100-001
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Sootblower #2

	 	220-223-100-002
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Sootblower #3

	 	220-223-100-003
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Sootblower #4

	 	220-223-100-004
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Sootblower #5

	 	220-223-100-005
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Stack

	 	610-614-100-002
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Stainless Steel Lab Sink

	 	170-179-300-001
	 	D19	 	 	 	 
	Area ‘K’ Steam Sample Cooler

	 	510-518-100-001
	 	D19
	 	Process Power & Equipment
Sales, Inc.	 	 
	Area ‘K’ Truck Reclaimer Reciprocating
Floor

	 	430-433-200-001
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Truck Unloading Hydraulic
System

	 	430-431-100-001
	 	D03
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Underfire Air Fan

	 	310-312-100-001
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘K’ Vacuum Breaker

	 	220-221-200-001
	 	D11D
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Air Accumulator

	 	530-533-400-003
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Air Compressor

	 	530-533-100-001
	 	D25	 	 	 	 
	Area ‘L’ Air Heater

	 	250-252-200-002
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Air Receiver

	 	530-533-400-001
	 	D25	 	 	 	 
	Area ‘L’ Amine to Steam Line Chemical
Pump #2

	 	510-515-300-002
	 	D24	 	 	 	 
	Area ‘L’ Ash Removal Drag Chain
Conveyor

	 	460-464-600-002
	 	D08
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Ash Roll-Off Dumpster

	 	460-461-400-002
	 	D08	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 2 Equipment List, Page 4

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Area ‘L’ BFW Pump #1

	 	540-541-100-003
	 	D12
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ BFW Pump #2

	 	540-541-100-004
	 	D12
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ BFW Sample Cooler

	 	510-518-100-006
	 	D20
	 	Process Power & Equipment
Sales, Inc.	 	 
	Area ‘L’ Biofuel Metering Bin

	 	440-443-200-002
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Blowdown Seperator Tank

	 	530-532-100-002
	 	D22
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Blowdown Sump Pump #1

	 	540-549-300-003
	 	D22	 	 	 	 
	Area ‘L’ Blowdown Sump Pump #2

	 	540-549-300-004
	 	D22	 	 	 	 
	Area ‘L’ Brine Tank

	 	510-512-100-006
	 	D19	 	 	 	 
	Area ‘L’ Building Exhaust Fan

	 	160-161-300-002
	 	D27	 	 	 	 
	Area ‘L’ Building Supply Fan

	 	160-161-200-002
	 	D27	 	 	 	 
	Area ‘L’ CBD Sample Cooler

	 	510-518-100-005
	 	D20
	 	Process Power & Equipment
Sales, Inc.	 	 
	Area ‘L’ Coalescing Prefilter

	 	530-533-700-001
	 	D25	 	 	 	 
	Area ‘L’ DCS of PLC System (BFW)

	 	720-725-100-004	 	 	 	 	 	 
	Area ‘L’ DCS or PLC System (Boiler)

	 	720-725-100-003
	 	 	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Deaerator

	 	530-531-100-002
	 	D12
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Duplex Water Softener A

	 	510-512-100-004
	 	D20	 	 	 	 
	Area ‘L’ Duplex Water Softener B

	 	510-512-100-005
	 	D19	 	 	 	 
	Area ‘L’ Electric Heater #1

	 	160-162-500-004
	 	D27	 	 	 	 
	Area ‘L’ Electric Heater #2

	 	160-162-500-005
	 	D27	 	 	 	 
	Area ‘L’ Electric Heater #3

	 	160-162-500-006
	 	D27	 	 	 	 
	Area ‘L’ Feeder Magnet

	 	430-438-400-002
	 	D04	 	 	 	 
	Area ‘L’ Fly Ash Multiclone

	 	320-321-100-003
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Fly Ash Reinjection Fan

	 	610-244-100-002
	 	D08
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Fly Ash Rotary Air Valve #1

	 	320-321-200-004
	 	D08
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Fly Ash Rotary Air Valve #2

	 	320-321-200-005
	 	D08
	 	Hurst Boiler & Welding Co., Inc.	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 2 Equipment List, Page 5

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Area ‘L’ Fuel Oil Back-Up Burner

	 	240-241-200-002
	 	D16
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Fuel Oil Pump

	 	240-243-100-001
	 	D16
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Fuel Oil Pump #1 (ON HOLD)

	 	HOLD
	 	D14	 	 	 	 
	Area ‘L’ Fuel Oil Pump #2 (ON HOLD)

	 	HOLD
	 	D14	 	 	 	 
	Area ‘L’ Fuel Oil Storage Tank

	 	520-523-100-001
	 	D14	 	 	 	 
	Area ‘L’ Fuel Sizing Screen

	 	440-441-100-002
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Hybrid Boiler

	 	210-213-100-002
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Hydrazine to DA Chemical
Pump #1

	 	510-515-100-002
	 	D24	 	 	 	 
	Area ‘L’ ID an

	 	310-311-200-002
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Inclined Drag Chain Conveyor

	 	430-436-100-002
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ MCC/PLC Room A.C.

	 	160-162-300-002
	 	D27	 	 	 	 
	Area ‘L’ Metering Bin Screw Conveyor
#1

	 	430-432-100-003
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Metering Bin Screw Conveyor
#2

	 	430-432-100-004
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Non Return Valve

	 	220-221-100-002
	 	D-0
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Oil Burner Fan

	 	310-313-100-002
	 	D16
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Overfire Air Fan

	 	310-314-100-002
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Particulate Afterfilter

	 	530-533-700-002
	 	D25	 	 	 	 
	Area ‘L’ Phosphate to BFW Chemical
Pump #3

	 	510-515-200-002
	 	D24	 	 	 	 
	Area ‘L’ Pit Sump Pump

	 	540-549-300-006
	 	D04	 	 	 	 
	Area ‘L’ Reciprocating Floor Hydraulic
System

	 	430-438-70-002
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Reciprocating Grate Stoker’

	 	230-231-300-002
	 	D08
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Reclaim Vibratory Feeder

	 	430-432-200-001
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Refrigerant Air Dryer

	 	530-533-500-001
	 	D25	 	 	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

	 	 	 

	Final Proposal — April 21, 2008

	 	Biomass Cogeneration Facility and Heating Plants
	Ameresco Federal Solutions

	 	Savannah River Site
	Appendix C, ECM 2 Equipment List, Page 6

	 	Contract DE-AM36-02NT41457

	 	 	 	 	 	 	 	 	 
	Equipment Description	 	Equipment #	 	P&ID	 	Company	 	Misc. Notes
	Area ‘L’ Safety Eyewash & Shower
	 	170-176-200-002
	 	D20	 	 	 	 
	Area ‘L’ Sootblower #1
	 	220-223-100-006
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Sootblower #2 
	 	220-223-100-007
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Sootblower #3 
	 	220-223-100-008
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Sootblower #4 
	 	220-223-100-009
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Sootblower #5 
	 	220-223-100-010
	 	D05
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Stack 
	 	610-614-100-001
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Stainless Steel Lab Sink 
	 	170-179-300-002
	 	D20	 	 	 	 
	Area ‘L’ Steam Sample Cooler 
	 	510-518-100-004
	 	D20
	 	Process Power & Equipment
Sales, Inc.	 	 
	Area ‘L’ Truck Reclaimer Reciprocating
Floor 
	 	430-433-200-002
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Truck Unloading Hydraulic
System 
	 	430-431-100-002
	 	D04
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Underfire Air Fan 
	 	310-312-100-002
	 	D06
	 	Hurst Boiler & Welding Co., Inc.	 	 
	Area ‘L’ Vacuum Breaker 
	 	220-221-200-002
	 	D12
	 	Hurst Boiler & Welding Co., Inc.	 	 

Use or disclosure of data contained on this sheet is subject to the restriction on the first page of this proposal

 

 

 

 

 

 

	 	 	 	 	 	 	 	 	 	 	 
	Station	 	Description	 	 	 	 
	No.	 	% moisture	 	wood/325	 	TDF/325
	1	 	Fuel , % Btu (LHV)
	 	 	 	 	 	 	 	 
	 	 	wood
	 	 	100.0	%	 	 	70.0	%
	 	 	TDF
	 	 	0.0	%	 	 	30.0	%
	 	 	DGS
	 	 	0.0	%	 	 	0.0	%
	 	 	Fuel, TPY
	 	 	 	 	 	 	 	 
	 	 	wood
	 	 	184,769	 	 	 	128,575	 
	 	 	TDF
	 	 	0	 	 	 	13,246	 
	 	 	DGS
	 	 	0	 	 	 	0	 
	 	 	 
	 	 	 	 	 	 	 	 
	 	 	B.D. Blend Analysis
	 	 	 	 	 	 	 	 
	 	 	Carbon, %:
	 	 	50.80	 	 	 	56.08	 
	 	 	Hydrogen, %:
	 	 	6.00	 	 	 	6.47	 
	 	 	Sulfur, %:
	 	 	0.08	 	 	 	0.15	 
	 	 	Oxygen, %:
	 	 	41.43	 	 	 	35.29	 
	 	 	Nitrogen, %:
	 	 	0.37	 	 	 	0.44	 
	 	 	Chlorine, %:
	 	 	0.00	 	 	 	0.00	 
	 	 	Ash/Other, %:
	 	 	1.32	 	 	 	1.38	 
	 	 	As Fired Moisture, %:
	 	 	50.00	 	 	 	45.43	 
	 	 	As Fired HHV BTU/lb:
	 	 	4,300	 	 	 	5,338	 
	 	 	As Fired LHV BTU/lb:
	 	 	3,509	 	 	 	4,545	 
	 	 	Flowrate lb/hr:
	 	 	42,185	 	 	 	32,379	 
	 	 	H MBtu/hr, LHV:
	 	 	148.02	 	 	 	147.15	 
	 	 	Ash + Lime Flow, lb/hr:
	 	 	397	 	 	 	413	 
	 	 	Limestone lb/hr:
	 	 	105	 	 	 	165	 
	 	 	 
	 	 	 	 	 	 	 	 
	2	 	FD Fan
	 	 	 	 	 	 	 	 
	 	 	Ambient Air lb/hr:
	 	 	175,100	 	 	 	183,000	 
	 	 	Total Air Flow lb/hr:
	 	 	175,100	 	 	 	183,000	 
	 	 	Temp oF:
	 	 	80	 	 	 	80	 
	 	 	ACFM:
	 	 	40,200	 	 	 	42,000	 
	 	 	dPress in WC:
	 	 	52	 	 	 	52	 
	 	 	Theor Power Hp:
	 	 	450	 	 	 	470	 
	 	 	Excess Air:
	 	 	35	%	 	 	44	%
	 	 	 
	 	 	 	 	 	 	 	 
	3	 	Bed
	 	 	 	 	 	 	 	 
	 	 	Surface area, ft2:
	 	 	873	 	 	 	873	 
	 	 	Heat trans., MBtu/hr:
	 	 	29	 	 	 	30	 
	 	 	Bed Dia, ft:
	 	 	0.00	 	 	 	0	 
	 	 	Bed Width, ft:
	 	 	20.00	 	 	 	20.00	 
	 	 	Bed Length, ft:
	 	 	19.10	 	 	 	19.10	 
	 	 	Temp F:
	 	 	1,514	 	 	 	1,546	 
	 	 	 
	 	 	 	 	 	 	 	 
	4	 	Vapor Space
	 	 	 	 	 	 	 	 
	 	 	Temp F:
	 	 	1,760	 	 	 	1,790	 
	 	 	Surface area, ft2:
	 	 	650	 	 	 	650	 
	 	 	Heat trans., MBtu/hr:
	 	 	12	 	 	 	12	 
	 	 	 
	 	 	 	 	 	 	 	 
	 	 	Velocity fps:
	 	 	9.3	 	 	 	9.2	 
	 	 	Flowrate lb/hr:
	 	 	217,000	 	 	 	215,100	 
	 	 	ACFM:
	 	 	213,100	 	 	 	210,400	 
	 	 	 
	 	 	 	 	 	 	 	 
	5	 	Boiler
	 	 	 	 	 	 	 	 
	 	 	Gas Flow lb/hr:
	 	 	217,000	 	 	 	215,100	 
	 	 	ACFM:
	 	 	213,100	 	 	 	210,400	 
	 	 	Gas H MBtu/hr:
	 	 	112.08	 	 	 	109.81	 
	 	 	Boiler duty, M Btu/hr:
	 	 	73.89	 	 	 	73.07	 
	 	 	Steam Temp F:
	 	 	825	 	 	 	825	 
	 	 	Steam Press (psia):
	 	 	850	 	 	 	850	 
	 	 	Steam Flow lb/hr:
	 	 	120,000	 	 	 	120,000	 
	 	 	Ash lb/hr:
	 	 	100	 	 	 	100	 
	 	 	 
	 	 	 	 	 	 	 	 
	 	 	Consummables
	 	 	 	 	 	 	 	 
	 	 	Limestone — lb/hr
	 	 	105	 	 	 	165	 
	 	 	Ammonia-as aqueous, lb/hr
	 	 	71	 	 	 	317	 
	 	 	Hydrated Lime — lb/hr
	 	 	0	 	 	 	0	 
	 	 	 
	 	 	 	 	 	 	 	 
	 	 	Air Preheater/ SCAH
	 	 	 	 	 	 	 	 
	 	 	Gas In Temp, F:
	 	 	437	 	 	 	441	 
	 	 	Gas out Temp, F:
	 	 	325	 	 	 	325	 
	 	 	Air Out Temp, F
	 	 	269	 	 	 	262	 
	 	 	APH Duty., MBtu/hr:
	 	 	7.00	 	 	 	7.00	 
	 	 	SCAH Duty, M Btu/hr:
	 	 	0	 	 	 	0	 
	 	 	 
	 	 	 	 	 	 	 	 
	7	 	Economizer
	 	 	 	 	 	 	 	 
	 	 	Gas In Temp, F:
	 	 	685	 	 	 	685	 
	 	 	Gas out Temp, F:
	 	 	437	 	 	 	441	 
	 	 	H2O in Temp, F:
	 	 	370	 	 	 	370	 
	 	 	H2O Out Temp, F
	 	 	487	 	 	 	482	 
	 	 	Heat Trans., MBtu/hr:
	 	 	15.75	 	 	 	14.99	 
	 	 	Ash lb/hr:
	 	 	0	 	 	 	0	 
	 	 	 
	 	 	 	 	 	 	 	 
	10	 	Baghouse
	 	 	 	 	 	 	 	 
	 	 	flow, lb/hr
	 	 	217,017	 	 	 	215,106	 
	 	 	ACFM
	 	 	75,247	 	 	 	73,455	 
	 	 	Temp, F;
	 	 	325	 	 	 	325	 
	 	 	moisture, wt%:
	 	 	15.97	%	 	 	12.68	%
	 	 	H, MM Btu/hr
	 	 	15.59	 	 	 	14.91	 
	 	 	Ash lb/hr:
	 	 	294	 	 	 	306	 
	 	 	 
	 	 	 	 	 	 	 	 
	11	 	ID Fan
	 	 	 	 	 	 	 	 
	 	 	ACFM:
	 	 	75,247	 	 	 	73,455	 
	 	 	Temp, F:
	 	 	325	 	 	 	325	 
	 	 	SP, in H2O:
	 	 	19	 	 	 	19	 
	 	 	BHP
	 	 	341	 	 	 	333	 
	 	 	 
	 	 	 	 	 	 	 	 
	12	 	Stack
	 	 	 	 	 	 	 	 
	 	 	Gas Temp F:
	 	 	334	 	 	 	334	 
	 	 	Gas Flow lb/hr:
	 	 	217,017	 	 	 	215,106	 
	 	 	ACFM:
	 	 	76,134	 	 	 	74,321	 
	 	 	Enthalpy MBtu/hr:
	 	 	16.17	 	 	 	15.46	 
	 	 	Vol (dry)%O2:
	 	 	5.5	%	 	 	6.5	%
	 	 	Wt% H2O:
	 	 	16.0	%	 	 	12.7	%
	Overall balance	 	 	 	 	 	 	 	 
	 	 	 
	 	 	 	 	 	 	 	 
	Total energy Input, MBtu/hr HHV:	 	 	181.4	 	 	 	172.8	 
	Boiler Duty, MBtu/hr:	 	 	128.5	 	 	 	128.5	 
	 	 	 
	 	 	 	 	 	 	 	 
	Efficiency, %:	 	 	70.8	 	 	 	74.3	 

Rev 2 increase T out back to 325 F

THIS DOCUMENT CONTAINS CONFIDENTIAL AND PROPRIETARY INFORMATION DO NOT COPY OR DISTRIBUTE WITHOUT
WRITTEN PERMISSION FROM EPI

     Preliminary For information only

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	EPI Energy Products of Idaho
	 	 	 	 	 	 	4006 Industrial Ave. Coeur d’ Alene, Idaho 83814
	 	 	PROJ. MGR.	 	DATE	 	Idaho Energy Limited Partnership
	 	 	 	 	 	 	PROCESS FLOW DIAGRAM (Customary U.S. Units)
	 ORIGNTR	 	BY	 	DATE	 	Ameresco
	 CHECKED	 	mlm	 	11/19/07	 	Savannah River
	PROJ. ENG.	 	 	 	 	 	PROJECT	 	CODE	 	SHEET	 	OF	 	REV
	filename
	 	4 2 08	 	04/03/08	 	S07088	 	0201 	 	1	 	1	 	2

 

 

			
	Fluidized Bed Combustors
	 	Page 1 of 3

Fluidized bed combustion systems use a heated bed of sand-like material suspended (fluidized)
within a rising column of air to burn many types and classes of fuel. This technique results in a
vast improvement in combustion efficiency of high moisture content fuels, and is adaptable to a
variety of “waste type fuels. The scrubbing action of the bed material on the fuel particle
enhances the combustion process by stripping away the carbon dioxide and char layers that normally
form around the fuel particle. This allows oxygen to reach the combustible material much more
readily and increases the rate and efficiency of the combustion process.

Bed Recycle System

The key to EPI’s dominance of the difficult waste fuel combustion market is our patented bed
recycle system. EPI is the only company that offers uniform bed drawdown, integrated air cooling
and automatic cleaning and reinjection of the bed material. This innovative feature enables EPI
systems to operate on fuels with significant quantities of 4-inch minus noncombustible tramp
material (contaminants such as rocks, metal. etc.). In grate style systems, tramp materials and ash
slag can cause significant problems requiring a shutdown to correct. In other fluidized bed
systems, tramp materials can build to the point that fluidization is no longer possible allowing
clinkers to form. In these systems, a shutdown is usually also required to clean out the
accumulation.

Complete and Efficient Combustion.

The turbulence in the combustor vapor space combined with the tumultuous scouring effect and
thermal inertia of the bed material provide for complete, controlled and uniform combustion. These
factors are key to maximizing the thermal efficiency, minimizing char, and controlling emissions.
The high efficiency of a fluid bed combustor makes it particularly well suited to problem fuels
with low BTU value and high moisture characteristics. EPI’s systems have consistently achieved high
combustion efficiencies. In typical units, the carbon burnout percentages within the combustor are
well in excess of 99 percent.

Waste Fuel Diversity

EPI systems have operated on fuels as diverse as agricultural waste, municipal solid waste, wood
wastes, industrial and municipal sludges, plastic, tires and coal. Fluidized bed systems are also
capable of efficiently combusting fuels of varying consistency. EPI units have demonstrated the
ability to handle a variety of wastes within a single combustor. EPI’s San Joaquin Valley Energy
Project units have logged operating time over 68 varieties of agricultural and urban wood waste.
EPI’s patented bed cleaning system, which removes large non-combustible material from the bottom of
the bed, allows EPI units to burn otherwise problematic fuels with a minimal amount of processing.

 

 

			
	 	 	 
	Fluidized Bed Combustors
	 	Page 2 of 3

Low Emissions

Emissions from a fluidized bed unit are inherently lower than conventional technologies for the
following reasons:

		 	Low combustion temperatures and low excess air within the bed reduces the formation of certain
emissions such as NOx.
	 
		 	High combustion efficiency results in flue gases that contain low amounts of CO.
	 
		 	Emissions such as SOx and NOx may be abated within the fluidized bed system by
injecting limestone into the bed and ammonia into the vapor space.

These features of fluidized bed combustion, combined with EPI’s vast experience with a variety of
fuels have allowed EPI units to comply with some of the most stringent air quality regulations in
the country, including six operating plants in California. EPI units have consistently been
accepted as the Best Available Control Technology “BACT” by environmental regulatory agencies.

Favorable Ash Properties

The high combustion efficiency of a fluid bed results in a reduced amount of inorganic material as
fine ash. The remaining larger material consists mainly of non-combustibles, such as rocks, and
wire brought in with the fuel, and coarse sand-like neutral particles. Low combustion temperatures
in the fluidized bed minimize the formation of toxic materials that might go into the ash. Ash
samples from EPI systems have consistently tested nontoxic, and in many instances the ash is being
sold as input for other products such as cement.

Operating Flexibility

EPI’s fluidized bed systems have demonstrated the ability to operate under a wide range of load
conditions. The thermal “flywheel” effect of the bed material allows swings in moisture and heating
content of the fuel to be absorbed by the system without negative impact. Conversely, the low fuel
inventory present in the unit makes it very responsive to varying loads. The fluidized bed also
maintains efficiency during system turn-down. The operating flexibility demonstrated by existing
EPI units has proven quite valuable for some of EPI’s customers allowing them to take advantage of
utility incentive programs for generation that follows electric demand.

Low Operating Costs

The lack of moving parts in a fluid bed reduces maintenance costs and down time. EPI units have
achieved operating availabilities above 98% and have kept operating costs relatively low given the
difficult fuels they are burning.

Environmentally Sound Energy Production from Waste

Fluidized bed combustion is an environmentally favorable, proven technology for disposal of solid
wastes and generation of energy. The combination of EPI’s vast experience in developing solutions
for a wide variety of applications, with the favorable characteristics of

 

 

			
	 	 	 
	Fluidized Bed Combustors
	 	Page 3 of 3

fluidized bed combustion make EPI the leader in providing environmentally sound waste disposal
solutions.

Energy Products of Idaho

4006 Industrial Ave

Coeur d’Alene, Idaho USA 83815-8928

Phone (208) 765-1611 ~ Fax (208) 765-0503

Email: epi2@energyproducts.com

Copyright © 2008 Energy Products of Idaho

Last modified: April 3, 2008

*

 

 

Benefits of Fluidized Bed Combustion

Fluidized bed combustion systems use a heated bed of sand-like material suspended (fluidized)
within a rising column of air to burn many types and classes of fuel. This technique results in a
vast improvement in combustion efficiency of high moisture content fuels, and is adaptable to a
variety of “waste” type fuels. The scrubbing action of the bed material on the fuel particle
enhances the combustion process by stripping away the carbon dioxide and char layers that normally
form around the fuel particle. This allows oxygen to reach the combustible material much more
readily and increases the rate and efficiency of the combustion process.

Bed Recycle System

The key to EPI’s dominance of the difficult waste fuel combustion market is our patented bed
recycle system. EPI is the only company that offers uniform bed drawdown, integrated air cooling
and automatic cleaning and reinjection of the bed material. This innovative feature enables EPI
systems to operate on fuels with significant quantities of 4-inch minus noncombustible tramp
material (contaminants such as rocks, metal etc.). In grate style systems, tramp material and ash
slag can cause significant problems requiring a shutdown to correct. In other fluidized bed
systems, tramp material can build to the point that fluidization is no longer possible allowing
clinkers to form. In these systems, a shutdown is usually also required to clean out the
accumulation.

Complete and Efficient Combustion

The turbulence in the combustor vapor space combined with the tumultuous scouring effect and
thermal inertia of the bed material provide for complete, controlled and uniform combustion. These
factors are key to maximizing thermal efficiency, minimizing char, and controlling emissions. The
high efficiency of a fluid bed combustor makes it particularly well suited to problem fuels with
low Btu value and high moisture characteristics. EPI’s systems have consistently achieved high
combustion efficiencies. In typical units, the carbon burnout percentages within the combustor are
well in excess of 99 percent.

Waste Fuel Diversity

EPI systems have operated on fuels as diverse as agricultural waste, municipal solid waste, wood
wastes, industrial and municipal sludges, plastic, tires and coal. Fluidized bed systems are also
capable of efficiently combusting fuels of varying consistency. EPI units have demonstrated the
ability to handle a variety of wastes within a single combustor. EPI’s San Joaquin Valley Energy
Project units have logged operating time on over 68 varieties of agricultural and urban wood waste.
EPI’s patented bed cleaning system, which removes large non-combustible material from the bottom of
the bed, allows EPI units to burn otherwise problematic fuels with a minimal amount of processing.

 

 

			
	Benefits of Fluidized Bed
Combustion continued...
	 	Page 2

Low Emissions

Emissions from a fluidized bed unit are inherently lower than conventional technologies for the
following reasons:

	•	 	Low combustion temperatures and low excess air within the bed reduce the
formation of certain emissions such as NOx.
	 
	•	 	High combustion efficiency results in flue gases that contain low amounts of CO.
	 
	•	 	Emissions such as SOx and NOx may be abated within the fluidized bed system
by injecting limestone into the bed and ammonia into the vapor space.

These features of fluidized bed combustion, combined with EPI’s vast experience with a variety of
fuels have allowed EPI units to comply with some of the most stringent air quality regulations in
the country, including six operating plants in California. EPI units have consistently been
accepted as the Best Available Control Technology “BACT” by environmental regulatory agencies.

Favorable Ash Properties

The high combustion efficiency of a fluid bed results in a reduced amount of inorganic material as
fine ash. The remaining larger material consists mainly of non-combustibles, such as rocks and
wire brought in with the fuel, and coarse sand-like neutral particles. Low combustion temperatures
in the fluidized bed minimize the formation of toxic materials that might go into the ash. Ash
samples from EPI systems have consistently tested nontoxic, and in many instances the ash is being
sold as input for other products such as cement.

Operating Flexibility

EPI’s fluidized bed systems have demonstrated the ability to operate under a wide range of load
conditions. The thermal “fly-wheel” effect of the bed material allows swings in moisture and
heating content of the fuel to be absorbed by the system without negative impact. Conversely, the
low fuel inventory present in the unit makes it very responsive to varying loads. The fluidized bed
also maintains efficiency during system turn-down. The operating flexibility demonstrated by
existing EPI units has proven quite valuable for some of EPI’s customers allowing them to take
advantage of utility incentive programs for generation that follows electric demand.

Low Operating Costs

The lack of moving parts in a fluid bed reduces maintenance costs and down time. EPI units have
achieved operating availabilities above 98% and have kept operating costs relatively low given the
difficult fuels they are burning.

Environmentally Sound Energy Production from Waste

Fluidized bed combustion is an environmentally favorable, proven technology for disposal of solid
wastes and generation of energy. The combination of EPI’s vast experience in developing solutions
for a wide
variety of applications, with the favorable characteristics of fluidized bed combustion make EPI
the leader in providing environmentally sound waste disposal solutions.

 

 

			
	 	 	 
	HD SERIES
	 	Fire Tube / Water Tube Hybrid
	 
	 	Design

			
	 	 	 
	 
	 	Fires on any liquid or gaseous fuel.
	 
	 	Sizes from 100 to 2500 horsepower
	
	 	with pressures to 450 PSI.
	The Only Boiler with the

Recovery of a Watertube and the
Thermal Reserve of a Firetube...
	 	 

This model features an external furnace, which opens a whole new range for packaged boilers.

Inherently low heat release enhances firing performance to reach outputs and emissions requirements

not possible with other shell type boilers.

	 	 	 	 	 	 	 

	Designed, constructed and stamped
in accordance with the requirements
of the ASME Boiler Codes.

	 	
	 	
	 	Inspected and registered with
the National Board of Boiler &
Pressure Vessel Inspectors.

 

 

	§	 	Efficient 2-Pass Design
	 
	§	 	Flexibility- Gas, Oil, Heavy Oil and Combination Gas/Oil
	 
	§	 	ASME Code Constructed & Stamped for 15 PSI Steam/30 Water
	 
	§	 	Registered with the National Board of Boiler Inspectors
	 
	§	 	Competitively Priced, Easily maintained, Designed for Efficiency
	 
	§	 	Large Furnace Volume for Ultimate Combustion Efficiency
	 
	§	 	Unified Refractory Base Floor
	 
	§	 	Steel Skids / Lifting Eyes
	 
	§	 	Easy Access to fireside Surfaces
	 
	§	 	Low Heat Release — 5 Sq. Ft./HP.
	 
	§	 	Ample Waterside Cleanout Openings
	 
	§	 	Fully Automatic Operations
	 
	§	 	U.L. Listed, Forced Draft Burners
	 
	§	 	Hybrid (Water/Fire Tube) Design
	 
	§	 	U.L. Listed Controls & Trim

STANDARD FEATURES

Durability - Built in accordance with the ASME Code, the wet back design has proven to give much
longer useful life cycles than dry back boilers.

Quality - Each unit is tested and inspected and registered with the National Board of Boiler and
Pressure Vessel Inspectors.

Design - Hurst Boiler utilizes state of the art computer design techniques in every boiler. This
accounts for accurate calculations of construction materials and optimum utilization of the
boiler’s performance criteria.

Combustion - Hurst uses name brand burner components with proven reliability. Every unit is
boiler/burner compatible and tested at the factory prior to shipment.

Standard Steam Trim

	•	 	Operating & limit pressure control
	 
	•	 	Modulating pressure control (when appl.)
	 
	•	 	Water column with gauge glass probe type combination low water cut-off & pump control (not shown)
	 
	•	 	Probe type auxiliary low water cut-off with manual reset
	 
	•	 	Water column drain valve
	 
	•	 	Safety relief valve(s) per ASME Code
	 
	•	 	Steam Gauge

Standard Water Trim

	•	 	Operating & limit temperature control
	 
	•	 	Modulating temperature control (when appl.)
	 
	•	 	Low water cut-off control with manual reset
	 
	•	 	Combination pressure, temperature gauge
	 
	•	 	Hot water return baffle for shock resistance
	 
	•	 	Safety relief valve(s) per ASME Code
	 
	•	 	Stack thermometer

 

 

The Hurst HD Hybrid Series combines the benefits of a watertube furnace along with a multi-pass
firetube boiler vessel. The resulting efficiency of the Hybrid design is higher than conventional
packaged boilers. This efficiency is achieved by superior utilization of the fuel’s radiant heat
within the water-cooled furnace as well as the Hybrid’s balanced multi-pass firetube vessel
resulting in low stack temperatures.

The HD Series will efficiently burn any liquid or gaseous fuel and is available from 100 to 2500
horsepower with pressures of 160-PSI hot water or 450-PSI steam.

 

 

Solid Fuel Fired Steam Boilers

Hurst Hybrid Series involves years of engineering and construction of the wood, coal, and solid
waste fired fuel systems.  
The Hybrid design combines the benefits of a watertube furnace along
with a multipass firetube boiler vessel. The resulting efficiency of the Hybrid design is higher
than conventional solid fuel boilers. This efficiency is achieved by superior utilization of the
fuels radiant heat within the water cooled furnace as well as the Hybrid’s balanced multi-pass
firetube vessel resulting in low stack temperatures. The Hybrid is adaptable to dry wood, wet wood,
coal and an array of other waste fuels. Furthermore, the watertube furnace allows for efficient
firing of auxiliary fuels (gas, fuel oil, and waste oil).

FEEDWATER DEAERATORS

WHY DEAERATE?

     The use of deaerators has long been used in power plants and water tube type boilers, primarily
because they remove undissolved oxygen and raise the temperature of the feedwater. These advantages
are important today for firetube boilers as well, due to higher capital investments.

     Operating costs can be reduced by recovering flash steam when returned by high temperature
condensate. This feature also raises the feedwater temperature, thus requiring less boiler fuel to
convert the feedwater to useable steam.

     Boiler tubes, condensate lines, and process piping have a much longer useful life by eliminating
the pitting action of untreated water. This advantage alone justifies the cost of an “OXY-MISER”
deaerator.

hurstboiler.com

	 	 	 	 	 

	P. O. Drawer 529

	 	Represented by:	 	 
	21971 Highway 319 N.
	 	 	 	 
	Coolidge, Georgia 31738
	 	 	 	 
	1-877-994-8778 (Toll Free)
	 	 	 	 
	(229) 346-3545 (Tel.)
	 	 	 	 
	(229) 346-3874 (Fax.)
	 	 	 	 
	e-mail: info@hurstboiler.com

	 	 	 	Revised 07/03

 

 

Hurst Boiler & Welding Co., Inc.

Post Office Box 529

Coolidge, Georgia 31738

			
	 	 	 
	Phone: 229-346-3545
	 	Fax: 229-346-3874

PROPOSAL NUMBER: 121807-300/150

300 HORSEPOWER / 150 PSIG DESIGN

WOOD WASTE FIRED STEAM BOILER

(10,350 POUNDS OF STEAM PER HOUR)

FOR

ESI, INC. OF TENNESSEE

1250 ROBERTS BOULEVARD

KENNESAW, GEORGIA 30144

ATTENTION: MR. JIM PITMAN, P.E.

JOB SITE: SAVANNAH RIVER

 

 

GENERAL SPECIFICATIONS

300 HORSEPOWER BOILER / 150 PSIG DESIGN

	 	 	 	 	 

	1.

	 	Scope of Equipment:
	 	300 Horsepower / 150 psig
	 

	 	 	 	Design Wet Wood Fired
	 

	 	 	 	Boiler to include:
	 
	 	 	 	 
	 

	 	 	 	- Deaerator
	 

	 	 	 	- Oil back-up burner
	 

	 	 	 	- Combustion air pre-heater
	 

	 	 	 	- Stack, 100’ free standing
	 

	 	 	 	- Recprocating floor, 6 section
	 

	 	 	 	- Cross-over conveyor with screen
	 
	 	 	 	 
	2.

	 	Fuel Requirements:
	 	11/2" x 21/2" x 5/8" or less in size
and 50% by weight or less in
moisture content.
	 
	 	 	 	 
	3.

	 	Approximate Fuel Usage at
Maximum Firing Rate:
	 	3200 lbs. per hour based on
50% moisture content.
	 
	 	 	 	 
	4.

	 	Boiler Rating:
	 	300 Boiler horsepower (10,350
lbs. of steam per hour from
and at 212o f)
	 
	 	 	 	 
	5.

	 	Boiler Pressure:
	 	150 psig design. 

Maximum recommended
operating pressure is
135 psig
	 
	 	 	 	 
	6.

	 	Boiler Design:
	 	High Pressure Hybrid

(Fire Tube/Water Tube Design)

Built in accordance with the

ASME Code

2 of 21

ESI, INCORPORATED.

 

 

1.1 ENGINEERING SERVICES

Hurst Boiler & Welding Co., Inc. will supply all required design and specifications for the
proposed equipment.

Engineering will include:

	 	1.	 	Boiler room/storage layout drawings for locating new equipment.
	 
	 	2.	 	Foundation details for proposed waste fired boiler based on 2000 PSF soil conditions.
	 
	 	3.	 	Assistance in completing and filing of boiler’s environmental emission permit.
	 
	 	4.	 	All required installation prints and specifications required to install the proposed equipment.
	 
	 	5.	 	Two (2) sets of operating and maintenance manuals.

3 of 21

ESI, INCORPORATED.

 

 

1.2 SYSTEM START-UP

When installation is complete, Hurst Boiler & Welding Co., Inc. will start the equipment and train
personnel on the proper maintenance and operation of the system to include:

	1.	 	Check out of all system components to assure proper rotation, alignment, sequencing, function,
etc.
	 
	2.	 	Start-up of the system to test operation of controls, conveyors and other related equipment.
	 
	3.	 	Adjustment of controls to provide efficient operation of all boiler functions
	 
	4.	 	Start-up of the equipment with mill personnel to familiarize them with proper operation and
maintenance procedure.
	 
	5.	 	Hurst Boiler & Welding Co., Inc.’s personnel will be on site until all equipment is started-up
and operating to the satisfaction of the Purchaser. Start-up services are a part of this proposal,
and no additional charges will be billed to the purchaser for these services.
	 
	6.	 	Hurst Boiler & Welding Co., Inc. start-up personnel will be on site for a minimum of ten days.

4 of 21

ESI, INCORPORATED.

 

 

2.1 WOOD FUEL GASIFIER

Substochiometric wood fuel gasifier to include:

	1.	 	Metering bin / retort type underfed stoker complete with AC-type variable speed controller
	 
	2.	 	Cast-iron grates with angle and tee bars
	 
	3.	 	Substochiometric combustion air system to include:

	 	•	 	Dual belt driven blowers with VFD, TEFC motor and OSHA belt guard
	 
	 	•	 	Zoned undergrate plenum.

	4.	 	Gasification chamber casing to include:

	 	•	 	Furnace front of 1/2" steel plate
	 
	 	•	 	Furnace sides and rear of 1/4" steel plate reinforced with angle and channel irons

	5.	 	Chamber lining of:

	 	•	 	9" refractory wall, and radiant arch with a service temperature of: 3000F
	 
	 	•	 	2" “M” block, service temperature of: 1900F
	 
	 	•	 	2" mineral wool, service temperature: 1200F

	6.	 	Two air cooled observation ports with heat shields and tinted site glasses
	 
	7.	 	Two cast iron overfire access doors with heat shield and lockable handles
	 
	8.	 	Undergrate access doors
	 
	9.	 	Skids and support assembly.

5 of 21

ESI, INCORPORATED.

 

 

2.2 WOOD GAS BURNER

For the combustion of fuel gas Hurst Boiler & Welding Co., Inc. will furnish:

	1.	 	Combustion air system to include:

	 	•	 	Belt driven blower with VFD, TEFC motor and OSHA belt guard
	 
	 	•	 	Prefabricated combustion air duct work for interconnection of blower to zoned air port plenum.

	2.	 	Combustion chamber casing complete with the following:

	 	•	 	Casing of 1/4" steel plate with inlet and outlet flanges
	 
	 	•	 	Angle and channel iron reinforcement

	3.	 	Chamber lining of:

	 	•	 	9" refractory wall, and radiant arch with a service temperature: 3000F
	 
	 	•	 	2" “M” block, service temperature: 1900F
	 
	 	•	 	2" mineral, wool, service temperature: 1200F.

In addition, one #2 oil fired burner, rated same as boiler, will be provided.

6 of 21

ESI, INCORPORATED.

 

 

2.3 PRESSURE VESSEL

Hurst Hybrid boiler with extended waterwall radiant section designed for efficient heat recovery
from solid fuel combustion. Unit built in strict accordance with the ASME Code and stamped, and
rated at no less than 6.5 square feet of heating surface per boiler horsepower.

	1.	 	The generator (firetube) section includes:

	 	•	 	Front and rear smoke boxes complete with twin hinged air tight doors. Doors internally insulated
and incorporate abrasion resistant shield on the interior of the doors.
	 
	 	•	 	Steam, water inspection and blowdown openings.
	 
	 	•	 	Lugs for connecting support structure.

	2.	 	The radiant (watertube) section includes:

	 	•	 	1/2" front plate and rear plate.
	 
	 	•	 	Support assembly for attaching to combustion chamber casing.
	 
	 	•	 	Blowdown openings on each lower drum.
	 
	 	•	 	Flanged inspection openings on the end of each drum.

	3.	 	Both the generator and radiant sections of the Hybrid boiler are insulated with 2” of high
density fiberglass and clad with 22 gauge “Paint-Grip” zinc coated steel jacket material and
galvanized screws for attachment and joining

	4.	 	Pressure vessel manufactured by Hurst Boiler & Welding Co., Inc. and guaranteed to be free from
defects in materials and workmanship for a period of one year.

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2.4 BOILER TRIM AND LIMIT CONTROLS

	1.	 	Relief valves per ASME Code

	2.	 	Boiler bottom blowdown valves

	 	•	 	Two (2) in generator section, quick-opening
	 
	 	•	 	Two (2) in radiant section, quick-opening
	 
	 	•	 	One (1) slow opening

	3.	 	Surface blowdown valves consisting of one (1) needle and one (1) check
	 
	4.	 	Main steam valving to include: angle non-return, pp spool and gate per ASME.
	 
	5.	 	Steam line necessary for the installation of the steam flow
transmitter, approximately 20'
	 
	6.	 	Chemical feed valves consisting of one (1) gate and two (2) check valves
	 
	7.	 	Steam pressure gauge with pigtail and gauge cock.
	 
	8.	 	Boiler feedwater valving to include: globe valve, two (2) check valves and stop valve.
	 
	9.	 	Low water limits:

	 	•	 	Primary: Probe type with tricocks, gauge glass and pump controller
	 
	 	•	 	Secondary: Probe type. (Probe type high water cut-off)

	10.	 	Pressure limits include:

	 	•	 	Opening limit
	 
	 	•	 	High pressure limit
	 
	 	•	 	Low pressure limit
	 
	 	•	 	4-20 milliamp pressure transmitter for fuel feed /combination air modulation.

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	11.	 	Blowdown separator built in accordance with the ASME Code to include:

	 	•	 	Blowdown inlet (screwed)
	 
	 	•	 	Drain (flanged)
	 
	 	•	 	Vent (flanged)
	 
	 	•	 	Exhaust stack (flanged) to vent above building roof line.

	12.	 	Access platforms, ladders and one set of stairs will be provided to access:

	 	•	 	Rear smoke box
	 
	 	•	 	Water column
	 
	 	•	 	Feedwater valve train
	 
	 	•	 	Main steam valving
	 
	 	•	 	Induced draft fan

	13.	 	Soot blowers, fixed zone, air with necessary piping, header and valving.
	 
	14.	 	Necessary pipe and fittings for the installation of the above trim.
	 
	15.	 	Steam flow meter with totalizer and transmitter.

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2.5 POLLUTION CONTROL AND INDUCED DRAFT EQUIPMENT

HURST BOILER & WELDING CO., INC. GUARANTEES THIS PLANT NOT TO EXCEED THE EMISSION RATE OF .3#/
MILLION BTU INPUT OR MEET STATE EPA STANDARDS, WHICHEVER IS GREATER.

Pollution control and induced draft system provided for each boiler consisting of:

	1.	 	Flanged breeching, prefabricated of angle iron reinforced 3/16” steel plate for routing flue gas
from boiler to multi-clone
	 
	2.	 	Combustion air preheater, vertical configuration, oversized to include

	 	•	 	Collection hopper with flanged inlet, outlet and access door
	 
	 	•	 	Rotary airlock ash discharge valve with drive

	3.	 	Dry mechanical multiple cyclone flyash arrestor with 9” diameter clones to include:

	 	•	 	Collection hopper with flanged inlet, outlet and access door
	 
	 	•	 	Rotary airlock ash discharge valve with drive

	4.	 	Flyash conveyor to transfer flyash to boiler room exterior
	 
	5.	 	Flanged transition of angle iron reinforced 3/16” steel plate for routing flue gas from
multicyclone to induced draft fan
	 
	6.	 	Centrifugal type induced draft fan designed for combustion air service complete with:

	 	•	 	Pillow block roller bearings (located outside hot gas stream)
	 
	 	•	 	Heavy duty shaft with heat slinger
	 
	 	•	 	Variable frequency drive
	 
	 	•	 	TEFC motor, belt drive and OSHA belt guard

	7.	 	Ground mounted induced draft fan and 100’ self-supporting stack with EPA stack test ports.

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2.6 DEAERATING BOILER FEEDWATER SYSTEM

Deaerating boiler feedwater system, 22mpph to include:

	1.	 	12' support structure
	 
	2.	 	Factory insulation and jacketing
	 
	3.	 	Boiler feedwater pumps, two each for proposed boiler to include:

	 	•	 	Electric motors
	 
	 	•	 	Variable frequency drive
	 
	 	•	 	Suction manifold
	 
	 	•	 	Pump suction piping, isolation valving and strainers
	 
	 	•	 	Pump discharge manifold with isolation valving and pressure gauges

	4.	 	Water gauge glass set, pressure gauge and thermometer
	 
	5.	 	Over flow trap
	 
	6.	 	McDonnell Miller high and low water switches
	 
	7.	 	ASME safety relief valves
	 
	8.	 	Vent and vacuum breaker
	 
	9.	 	Steam pressure reducing valve, Fisher pneumatic globe valve
	 
	10.	 	Freshwater make-up valve, Fisher pneumatic globe valve
	 
	11.	 	Tank drain valve

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2.7 WOOD FUEL RECEIVING AND SYSTEM

Hurst Boiler & Welding Co., Inc. will provide one fuel storage facility to include:

	1.	 	Six section reciprocating floor to include:

	 	•	 	Hydraulic cylinders
	 
	 	•	 	Hoses and fittings

	2.	 	Concrete imbediment for mounting hydraulic cylinders
	 
	3.	 	Hydraulic power unit with reservoir and valve block
	 
	4.	 	Vibrating cross-over conveyor with fuel screening section
	 
	5.	 	Incline chain conveyor

	 	•	 	WD110 chain
	 
	 	•	 	UHMW ware plate
	 
	 	•	 	Shafts, sprockets, bearings and drive

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2.8 ELECTRICAL CONTROL SYSTEM

	 	 	An integrated control system housed in a free standing, pre wired panel for automatic operation
will be provided for each boiler to include:

	1.	 	Control Panel

	 	•	 	NEMA 12 control enclosure
	 
	 	•	 	Enclosure prefabricated of 10 gauge plate
	 
	 	•	 	Primed and painted interior and exterior.

	2.	 	Main disconnect
	 
	3.	 	Control voltage transformer
	 
	4.	 	Cooling as required, air to air exchanger
	 
	5.	 	Allen Bradley MicroLogix / 1756 System processor
	 
	6.	 	Power supply Rack Communication modules
	 
	7.	 	Input and output modules
	 
	8.	 	Allen Bradley RS View runtime package to represent system required parameters and variables
running on a desktop computer. Operator interface is through this interface.
	 
	9.	 	Allen Bradley PowerFlex 70 and 700 480v variable frequency drives
	 
	10.	 	Input line reactors
	 
	11.	 	DeviceNet communication to processor
	 
	12.	 	Variable frequency drives will be provided for:

	 	•	 	Metering bin drive
	 
	 	•	 	Underfire combustion air fan
	 
	 	•	 	Overfire combustion air fan
	 
	 	•	 	Induced draft fan

	13.	 	Local motor disconnects are provided at each motor

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	14.	 	Control enclosure is completely wired, shop tested and Includes terminal strip terminations,
ready for connection to field devices
	 
	15.	 	Control system incorporates equipment mounted, 4-20 milliamp transmitters for
controlling/monitoring:

	 	•	 	Steam flow
	 
	 	•	 	Steam pressure
	 
	 	•	 	Boiler water level
	 
	 	•	 	Furnace temperature

	16.	 	Limits and Alarms:

	 	 	 	 	 	 	 

	 

	•	Primary boiler low water
	 	Limit/Alarm
	 	Automatic Reset
	 
	 	 	 	 	 	 
	 

	•	 Secondary boiler low water
	 	Limit/Alarm
	 	Manual Reset
	 
	 	 	 	 	 	 
	 

	•	 High water cut-off
	 	Limit/Alarm
	 	Automatic Reset
	 
	 	 	 	 	 	 
	 

	•	 Low boiler steam pressure
	 	Alarm
	 	Automatic Reset
	 
	 	 	 	 	 	 
	 

	•	 High boiler steam pressure
	 	Limit/Alarm
	 	Automatic Reset
	 
	 	 	 	 	 	 
	 

	•	 Low draft (Furnace)
	 	Limit/Alarm
	 	Automatic Reset
	 
	 	 	 	 	 	 
	 

	•	 High temperature (Furnace)
	 	Limit/Alarm
	 	Automatic Reset

	17.	 	A separate feedwater pump panel will be provided for the proposed feedwater pumps to include
motor controls

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3.1 INSTALLATION SERVICES

To be installed by others than Hurst Boiler

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SAVANNAH RIVER PROJECT

CONDENSING / EXTRACTION

TURBINE GENERATOR SET

ADVANCED POWER PRODUCTS

PROJECT 10167 Rev 2

March 26, 2008

 

 

1. Turbine general description

The machine is an extraction-condensing multistage steam turbine, model TMCE 25000A manufactured
by TGM Turbines. The machine is provided with a horizontally split casing. The top portion has a
built-in block with independent steam control valves, directly actuated by independent hydraulic
servo-motors, which provides excellent speed stability and part load performance.

There are two emergency trip valves, one installed at upper casing steam block and the other
is supplied loose to be installed in the client’s extraction steam line. Both are hydraulically
actuated.

The rotor consists of 01 control wheel and several stages which designed to meet the stated
performance. Wheels and shaft are made of a single and integral forged steel piece. The shaft
rests on tilting pads type radial and axial bearings.

The rotor assembly includes a balance piston, which compensates the axial forces acting on the
rotor by using the steam exhaust pressure to reduce the axial thrust. Labyrinth seals provide the
sealing.

The turbine is provided with thermal insulation and lagging in steel plates.

A sound enclosure can be provided over the turbine and gear to the reduce noise level below 85
dba.

The turbine and speed reducer is furnished on a common baseplate.

The complete lube oil system including the AC auxiliary oil pump, DC emergency oil pump, dual oil
coolers, dual oil filters, and oil reservoir are provided on a separate skid, The main oil pump is
shaft driven off the low speed side of the gear.

 

 

2. Turbine Technical Information

Operating Conditions

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Turbine model	 	TMCE 25000A	 	 	 	 
	Load point	 	1	 	2	 	3	 	 	 	 
	Power at generator output
	 	 	18,700	 	 	 	17,000	 	 	 	8,180	 	 	KW
	Inlet pressure
	 	 	850	 	 	 	850	 	 	 	850	 	 	Psia
	Inlet temperature
	 	 	825	 	 	 	825	 	 	 	825	 	 	 	o F	 
	Throttle flow
	 	 	240,000	 	 	 	240,000	 	 	 	240,000	 	 	Lb/h
	Extraction pressure
	 	 	385	 	 	 	385	 	 	 	385	 	 	Psig
	Extraction flow
	 	 	80,000	 	 	 	100,000	 	 	 	195,000	 	 	Lb/h
	Exhaust pressure
	 	 	3.3	 	 	 	2.7	 	 	 	1.5	 	 	“HgA
	Exhaust flow
	 	 	160,000	 	 	 	140,000	 	 	 	45,000	 	 	Lb/h
	Turbine speed
	 	 	6000	 	 	 	6000	 	 	 	6000	 	 	Rpm
	Generator speed
	 	 	1800	 	 	 	1800	 	 	 	1800	 	 	Rpm
	Tolerance
	 	 	1	 	 	 	—	 	 	 	—	 	 	 	%	 

Rotation direction – turbine: Counter Clockwise

	1)	 	Rotation direction seen from turbine to generator
	 
	2)	 	Gearbox efficiency (approx.): 98,5% Generator efficiency 97,6% (approx. WEG)

The above guaranteed performance is given with a tolerance of 1%, with all control valves
completely open, all blades free from scaling and cooling equipment with all cooling surfaces free
from deposits, in accordance with the rules of TGM procedure IT-AT-004_r1 of 07/01/2005 based on
ASME PTC 6.

	 	 	 

	Turbine Materials
	 	 
	Steam chest

	 	ASTM A 217 WC1
	Turbine Casing

	 	ASTM A 217 WC1
	Exhaust casing

	 	ASTM A 516 Gr.60
	Rotor (integral)

	 	SAE 4340
	Nozzles

	 	AISI 420
	Blades

	 	AISI 420
	Internal parts of valves

	 	SAE 4340
	Bearing lining

	 	Babbitt (white metal)
	Steam piping / Oil piping

	 	ASTM A 106 / AISI 304 (*)

 

			
	(*)	 	 Oil piping will be supplied in SS for pressure and return lines

Design parameters

Based on IEC standard, publishing 45:

Inlet steam pressure: 880 psig

Inlet steam temperature: 839,4 oF

 

 

Steam connections (turbine flanges)

	 	 	 	 	 	 	 
	 	 	Inlet	 	Extraction	 	Outlet
	DN (in)
	 	10	 	10	 	95 X 38
	PN (psi)
	 	900	 	600	 	30
	Norma
	 	ANSI B 16.5	 	ANSI B 16.5	 	—
	Direction
	 	Right - Downwards (*)	 	Up or Down	 	Up or Down

 

			
	(*) Seen from the turbine to the generator

Turbine protection system

The TGM trip valve for the TM turbine is provided with a special device that allows for testing the
valve during the turbine operation in compliance with the API 612 standard. The trip valve will
actuate whenever one or more conditions below occur:

	§	 	Overspeed (mechanical / electronic)
	 
	§	 	3-way solenoid valve (electric)   
	 
	§	 	Manual trip
	 
	§	 	Excessive radial bearings vibration
	 
	§	 	Excessive axial displacement   
	 
	§	 	High bearing metal temperature

Turbine governing system

By electronic Governor Woodward 505E, NEMA D, which operates via current- to- pressure converter on
the steam control valve servo-motors. The system includes:

Woodward 505 E governor

Woodward CPC (2)

Servo-motors by TGM

Magnetic pick-ups (3)

Noise Level

Approximate noise level for turbine and gearbox is 96db (A) ± 2, for measurements at 1 meter of
distance, not taking into account environmental conditions, based on ISO 3740 and VDI 2159
standards. Sound enclosure for turbine and gearbox is proposed as an option (See commercial offer)

Vibration Limits

As per ISO 10816 Standard, part 3 – group 1 – zone A/B, level below 2.3 mm/s for rigid support or
3.5 mm/s for flexible support

 

 

3. Gearbox, Turning Gear and Couplings

	 	 	 

	Gearbox
	 	 
	 
	 	 
	Type

	 	Parallel shafts, horizontally split casing
	Input power

	 	19240 kW
	Input/Output speed

	 	6000/1800 rpm
	Gearing type

	 	Double-helical
	Teeth

	 	Case hardened and grounded
	Bearing

	 	Babbitt
	Casing

	 	Cast iron
	Service Factor (AGMA)

	 	 1.3
	 
	 	 
	Turning Gear
	 	 
	Type

	 	Electric
	Power

	 	15 kW (approx.)
	Engage / disengage

	 	Manual / automatic
	 
	 	 
	Couplings
	 	 
	 
	 	 
	High Speed
	 	 
	 
	 	 
	Type 
	 	       Disk
	Speed 

	 	    6000 rpm
	Lubrication

	 	  Not required
	Protection

	 	SAE 1020 plate
	 
	 	 
	Low Speed
	 	 
	 
	 	 
	Type 
	 	       Rigid
	Speed 

	 	    1800 rpm
	Lubrication

	 	  Not required
	Protection

	 	SAE 1020 plate

 

 

     4. Hydraulic System

Main oil pump

	 	 	 

	§      Type

	 	Worm
	§      Oil pressure

	 	10 kgf/cm 2
	§      Driven by

	 	Low speed gearbox shaft
	§      Oil specification

	 	ISO VG 68
	 
	 	 
	Auxiliary oil pump
	 	 
	 
	 	 
	§      Type

	 	Worm
	§      Oil pressure

	 	10 kgf/cm 2
	§      Driven by

	 	Electric motor
	§      Current type

	 	A/C
	§      Frequency

	 	60 Hz
	§      Speed

	 	1760 rpm
	§      Configuration

	 	B 3
	§      Protection

	 	IP 55
	 
	 	 
	Emergency oil pump
	 	 
	 
	 	 
	§      Type

	 	Gear
	§      Oil pressure

	 	1,5 kgf/cm 2
	§      Driven by

	 	Electric motor
	§      Current type

	 	DC
	§      Speed

	 	1800 rpm
	 
	 	 
	Oil cooler duplex (Standard TGM)
	 	 
	 
	 	 
	§      Cooling water temperature inlet (max.)

	 	86 oF (*)
	§      Cooling water temperature outlet

	 	95 oF
	§      Oil inlet temperature

	 	140 oF
	§      Oil outlet temperature

	 	113 oF
	§      Pressure drop

	 	4 psig
	§      Cooling water pressure

	 	100 psig

 

			
	(*)	 	 To be confirmed by the customer

	 	 	 

	Materials
	 	 
	 
	 	 
	§      Tubes

	 	AISI 304
	§      Tubes sheets

	 	ASTM A 285 Gr. C
	§      Water chamber

	 	ASTM A 285 Gr. C
	§      Casing

	 	ASTM A 285 Gr. C

 

 

Hydraulic system – continuation

Oil filter (lubrication and control) – Turbine

	 	 	 

	§      Type

	 	Duplex
	§      Strainer mesh

	 	25 μm
	§      Pressure drop

	 	0,2 kgf/cm 2
	§      Strainer material

	 	Stainless steel

Oil tank

	 	 	 

	§      Oil type

	 	ISO VG 68
	§      Material

	 	Structural steel (carbon steel)

OBS.: Oil tank and lube oil system to be supplied separate from the turbine and gearbox baseplate.

Lube oil system to be mounted together with oil tank. Oil coolers will be positioned under the oil
tank.

 

 

5. Instrumentation

All variables, according to the list of instruments below, will be indicated through a local panel
to be installed beside the turbine.

Panel and indicators to be provided by APP. Instruments listed under column “LC = LOCAL” to be
provided by TGM.

	 	 	 	 	 	 	 	 	 	 	 
	Measurement points	 	QT	 	LC	 	PA	 	AL	 	TR
	Governing system
	 	 	 	 	 	 	 	 	 	 
	Woodward governor 505 E
	 	1	 	 	 	X	 	 	 	 
	CPC
	 	2	 	X	 	 	 	 	 	 
	Magnetic Pick-ups
	 	3	 	X	 	 	 	 	 	 
	Steam System
	 	 	 	 	 	 	 	 	 	 
	Inlet steam pressure
	 	1	 	PIT	 	PI	 	 	 	 
	Wheel chamber pressure
	 	1	 	PIT	 	PI	 	 	 	 
	Extraction pressure
	 	1	 	PIT	 	PI	 	 	 	 
	Exhaust pressure
	 	1/1	 	PIT/PS	 	PI	 	H	 	HH
	Inlet steam temperature
	 	1	 	TE	 	TI	 	 	 	 
	Extraction temperature
	 	1	 	TE	 	TI	 	 	 	 
	Exhaust steam temperature
	 	1	 	TE	 	TI	 	 	 	 
	Lubrication system
	 	 	 	 	 	 	 	 	 	 
	Pressure after oil pumps
	 	1	 	PIT	 	PI	 	 	 	 
	Oil pressure at gearbox inlet
	 	1	 	PI	 	 	 	 	 	 
	Lubrication oil pressure
	 	1/1	 	PIT/PS	 	PI	 	 	 	LL
	Differential pressure in the oil filter
	 	1	 	DPS	 	 	 	H	 	 
	Oil temperature before the oil cooler
	 	1	 	TI	 	 	 	 	 	 
	Oil temperature after the oil cooler
	 	1	 	TE	 	TI	 	H	 	 
	Turbine bearing metal temperature (RTD Pt 100)
	 	4	 	TE	 	TI	 	H	 	HH
	Gearbox bearing metal temperature (RTD Pt 100)
	 	4	 	TE	 	TI	 	H	 	HH
	Control System
	 	 	 	 	 	 	 	 	 	 
	Impulse oil pressure
	 	1/1	 	PIT/PS	 	PI	 	L	 	 
	Control oil pressure
	 	1	 	PIT	 	PI	 	 	 	 
	Others
	 	 	 	 	 	 	 	 	 	 
	Manual trip
	 	1	 	HV	 	HS	 	 	 	 
	Turbine trip indicator
	 	1	 	ZS	 	ZI	 	X	 	 
	Turbine speed
	 	1	 	SE	 	SI	 	 	 	HH
	Auxiliary oil pump motor (on-off)
	 	1	 	 	 	HS	 	 	 	 
	Oil tank low level
	 	1	 	LE	 	LI	 	L	 	 
	Electronic overspeed system
	 	1	 	SE	 	SI	 	H	 	HH
	Radial vibration probes – turbine
	 	4	 	VE	 	VI	 	H	 	HH
	Radial vibration probes – gearbox
	 	8	 	VE	 	VI	 	H	 	HH
	Radial vibration probes — generator
	 	4	 	VE	 	VI	 	H	 	HH
	Keyphasor
	 	1	 	ZE	 	ZI	 	H	 	HH
	Axial displacement – turbine (probes by TGM)
	 	2	 	ZE	 	ZI	 	H	 	HH

Remark:

1) Pressure/temperature transmitters, electric motors and magnetic pick-ups will be UL listed. CPC,
RTD’s, cables, cable trays, conduits, junction boxes and further instruments/accessories will be
supplied as per TGM standard.

 

 

Instrumentation (Continuation)

Legend

AL: Alarm

PS: Pressure switch

DPS: Differential pressure switch

TR: Trip

HS: Manual Key

LC: Local

LI: Level indicator

LT: Level transmitter

PA: Panel

PI: Pressure indicator

PIT: Pressure transmitter

L: Low signal

LL: Very low signal

SI: Rotation indicator

SE: Rotation sensor

TE: Temperature sensor

TI: Temperature indicator

VI: Vibration indicator

VE: Vibration sensor

VT: Vibration transmitter

ZE: Displacement sensor

ZI: Displacement indicator

ZS: Limit switch

H: High signal

HH: Very high signal

HV: Hand Valve

Instruments Voltage

	 	 	 	 	 	 	 
	Function	 	Voltage	 	Frequency	 	Observation
	Safety
	 	125 Vdc	 	 	 	 
	Auxiliary for control panel
	 	220 Vac
	 	60 Hz	 	 
	Instrumentation
	 	24 Vdc	 	 	 	 
	Direct current
	 	24 Vdc	 	 	 	 
	Auxiliary pump
	 	220/380/440 Vac
	 	60 Hz	 	 
	Emergency pump
	 	125 Vdc	 	 	 	 

OBS.: All voltages indicated above are generic. The customer shall confirm them all later on.

 

 

6. Switchgear & Controls

Medium Voltage Switchgear

	 	 	 

	 	 	Section #1 - Generator Section

	1	 	Vacuum Breaker Element, 1200A 15kV 500mVA

	1	 	Vacuum Breaker Compartment,1200A 5kV

	1	 	Vacuum Breaker MOC/TOC Switch

	1	 	Generator Voltage Transformer Drawout Tray

	1	 	Generator Control Transformer Drawout Tray

	1	 	Section, indoor vertical section

	1	 	Section, main copper buswork

	2	 	Voltage Transformers

	1	 	Control Power Transformer, 3kVA

	3	 	Current Transformers

	 	 	 

	 	 	Section #2 - Bus VTs

	1	 	Bus Voltage Transformer Drawout Tray

	1	 	Section, indoor vertical section

	1	 	Section, main copper buswork

	2	 	Voltage Transformers

	 	 	 

	1	 	Set, space heaters and cabinet lamps

	1	 	Set, breaker standard accessories

	1	 	Sets, control wire, wiretags, terminal blocks, fuses

	 	 	 

	Surge Cabinet
	 	 	 

	1	 	Vertical housing NEMA 4 Stainless Steel

	3	 	Lightning Arrestors

	3	 	Surge Capacitors

	1	 	Space Heater

	1	 	Cabinet Lamp

	1	 	PT drawout tray

	1	 	CPT drawout tray

	3	 	voltage transformers

	1	 	control transformer

	 	 	 

	Neutral Grounding Resistor
	 	 	 

	1	 	NGR, 400A 10 Second, NEMA 4 Stainless Steel enclosure

	3	 	Differential Current Transformers

 

 

	 	 	 

	Turbine / Generator Control Panel
	 	 	 

	 	 	NEMA 4 Stainless Steel vertical section w/vortex air cooler &

	1	 	temperature controller

	1	 	Woodward 505 Governor

	1	 	Woodward SPM-D11/LSXR Synchronizer

	1	 	Woodward Protech 203 Electronic Trip

	1	 	Basler DECS-200

	1	 	GE SR-489 Multilin Generator Protection Relay

	1	 	Lot, Test Blocks

	1	 	Synchroscope

	1	 	Lockout Relay

	16	 	Auxiliary Relays

	1	 	Lot, Control Switches

	1	 	Lot, Relay Surge Suppressors

	1	 	Space Heater

	1	 	Thermostat

	1	 	Interior Light

	1	 	Interior Light Switch

	1	 	Switch — Generator Circuit Breaker Trip/Close

	1	 	Switch — Governor Speed Lower/N/Raise

	1	 	Switch — AVR Voltage Lower/N/Raise

	2	 	24VDC Power supply-20A (redundant)

	1	 	Lot, Wire, Terminal blocks, fuses, fuseblocks

	1	 	Lot, commissioning spare parts

	1	 	Lot of Nameplates & Engraving

	1	 	Lot of Pilot Lights & Pushbuttons

	1	 	Lot of Meters (KW/Kvar/V/A, Frequency etc...)

	1	 	Lot, miscellaneous controls, etc

	 	 	PLC Control Material

	1	 	ControlLogix Processor, 64 MB CompactFlash (1756-L61))

	1	 	Backup Battery, (1756-BA1)

	1	 	ControlLogix Chassis, 17 slot (1756-A17)

	1	 	Controllogix Power supply, 75 Watts (1756-PA75/C)

	1	 	Prosoft Modbus Interface Card (MV156-MCM)

	1	 	Ethernet Interface Card (1756-ENBT)

	1	 	16-Channel Analog Input, single ended (1756-IF16)

	3	 	6-Channel RTD Input (1756-IR61)

	1	 	16-Input Card, AC (1756-IA16)

 

 

	 	 	 

	2	 	16-channel input Card , DC (1756-IB16)

	3	 	16-Relay Output Card, Isolated (1756-OW161)

	8	 	Removable Terminal Block, 36 point (1756-TBCH)

	4	 	Removable Terminal Block, 20 point (1756-TBNH)

	4	 	Extended Housing Terminal Block (1756-TBE)

	2	 	DH-485 Interface Module (1761-NET-AIC)

	1	 	PanelView+ 1000 w/Ethernet (2711P-T10C4A2)

	1	 	RSViewME Software for HMI (9701-VWSTMENE)

	1	 	Miscellaneous Communications Cables for HMI & PLC

	1	 	Industrial Network Switch (Hirschmann RS2-4TX/1FX)

	 	 	 

	Bently Nevada
	 	 	 

	1	 	19" Rack, 14 slots (P/N 3500/05-01-00-00-00)

	1	 	Rack Interface Module (P/N 3500/20-01-02-00)

	1	 	Rack Power Supply, 120VAC & 24VDC (P/N 3500/15-01- 04-00)

	1	 	Keyphasor Module (P/N 3500/25-01-01-00)

	5	 	Proximity/Seismic Monitor Module (P/N 3500/42-01-00)

	2	 	4-Channel Relay Module (P/N 3500/32-01-00)

	1	 	Communication Gateway, Modbus RS-485 (P/N 3500/92- 02-01)

	1	 	3-Channel Overspeed Protection System (P/N 3500/53- 03-00)

DC Emergency Oil Pump

Starter for emergency oil pump

Batteries a charger for DDC emergency oil pump

 

 

7. GENERATOR

GENERATOR 23125 kVA/ 13800 V/ 1800 rpm

Three phase synchronous generator, industrial type, with BRUSHLESS excitation system, electronic
voltage regulator, with welded steel frame, 1040/45 steel shaft, class “F” insulation (155oC),
sleeve bearings, CW and CCW rotation; manufactured according to ABNT and IEC standards, having the
following characteristics:

	 	 	 

	Quantity
	 	: 01
	Model
	 	: SSW 1000
	Frame
	 	: 1000
	Output
	 	: 23125 kVA
	Poles/ Nominal speed
	 	: 04 / 1800 rpm
	Over Speed
	 	: 20%
	Voltage
	 	: 13800 V
	Frequency
	 	: 60 HZ
	Power factor
	 	: 0,80
	Protection degree
	 	: IP-54
	Cooling system
	 	: Totally enclosed - 2 X 65% water-air cooled
	(CACW)
	 	 
	Mounting
	 	: B3 (Horizontal)
	Environment
	 	: 40OC and 1000 m
	Duty
	 	: S1
	Insulation class
	 	: F
	Temperature rise
	 	: 80OC
	Bearing type
	 	: Sleeve Bearing

 

 

ACCESSORIES INCLUDES:

-(06) Winding temperature detector (02 per phase): PT-100

-(02) Bearing temperature detector (01 per bearing): PT-100

- Space heaters, 220 V, 600 Watts;

- Oil Flow Sight-Viewer

- Water Flow Viewer

- Water Flow detector in the water inlet (heat exchanger)

- Water leakage detector

- Water temperature detector inlet and outlet: PT-100

- Air temperature detector inlet and outlet: PT-100

- Grounding Brush

- Neutral connection box

- Air water cooling system, two heat exchangers for each generator.

- Water leakage detector

- Bently Nevada Probes (DE + NDE bearings). Installed by WEG but supplied by

steam turbine manufacturer.

GENERAL INFORMATION:

APPLICABLE STANDARDS:

The machines are designed, manufactured and tested according to standards ABNT, NEMA, IEEE, IEC
and DIN, where applicable. Specifically we can mention:

NBR 5110 — Cooling methods.

NBR 5052 — Synchronous machines.

NBR 5117 — Synchronous machines.

ISO 1940 — Balancing quality.

VDE 0530 — Turning electrical machines.

NEMA MG-1 Part 32 and 33 — Synchronous Generators.

GENERAL CONSTRUCTION:

An alternating-current generator consists essentially of a magnetic circuit, dc field winding, ac
armature winding and mechanical structure, which includes cooling and lubrication. The magnetic
circuit and field windings are arranged in certain way that, as the machine spins, the magnetic
flow linking the armature windings

 

 

changes cyclically, and for this reason induces alternate voltage in armature winding.

There are many possible geometrical arrangements for these elements, and each one with its own
advantages. Usually the salient pole construction is used for low speed rotors such as the ones
used in diesel an hydroelectric power stations, and the cylindrical rotor machine for
steam-turbine driven generators. WEG’s standard for high-speed application is the cylindrical
rotor type because of the lower centrifugal forces created, and also because it
lessens/eliminates some harmonics and high frequency interference with other equipments.

FUNCTIONS:

The mechanical and electrical characteristics as well as the performance of an electric generator
are a consequence of the magnetic circuit design. Because output results from the interaction
between current-carrying armature conductors, the air-gap flux and it is proportional to their
product, when designing the magnetic circuit WEG design provides the correct space for the windings
and the right path for the magnetic flux.

DESIGNING THE MAGNECTIC CIRCUIT:

The right design of the pole pitch and the number of poles assures always the best path for the
circuit. As the number of poles decreases, the restrictions in space available in the rotor
result in most of the magnetic circuit dimensions being a smaller proportion of the pole pitch.
The armature slot width is determined principally by the insulation thickness required for the
machine voltage and is commonly such that the resulting total copper width per slot is 40 to 60%
of the slot width.

MATERALS AND LOSSES:

To reduce Foucault currents caused by variations of the air gap flux density, and also to reduce
losses in the rotor pole faces, WEG selected the cylindrical type rotor instead of the high
stressed salient pole machines. Always when this type of pole is used we notice the air gap is
relatively large and the losses decrease to acceptable values. Most salient-pole machines on the
other hand, have smaller air gaps relative to the armature slot widths.

To improve the good characteristics of the cylindrical-pole configuration, our design also use
laminated poles. We can use one-piece laminations or segmental laminations, depending on the
machine size and the available widths of the electrical sheet of steel. Mostly WEG uses 3.5%
silicon electrical sheet steel in 0.014 to 0.025 in thickness. This sheets are stamped at WEG,
because quality and grain orientation. The correct finishing includes polishing and painting

 

 

of each individual sheet. During testing, when submitted to high flux densities the advantages of
this construction come to view in the general efficiency.

PERFORMANCE:

The field current required for a particular load condition is determined by the magnetic circuit
in conjunction with its armature and field windings. This is calculated during design by
evaluating the flux densities and the corresponding ampere-turns in all parts of the magnetic
circuit. After the machine is built, the magnetic characteristics are shown in the performance
report.

FRAME:

WEG’s electric generator’s frames are built entirely using steel sheets and MIG welded profiles.
It’s well known by its strength and mechanical resistance. It can be manufactured in many different
arrangements, and the most usual ones are B3 (with terminal boxes placed sideways) or D5 whose
characteristics include pedestal bearings and terminal box located at the bottom of the generator,
inside air outlet.

CLASSES OF INSULATION:

To assure long electrical/overall life, the temperature of operation should never surpass the
insulation class temperature of the materials used in the generator construction.

As result, the table below shows standard temperatures for the most common classes used for
this size of generators:

	 	 	 	 	 
	Insulation Class	 	Temperature Class	 	Temperature rise oC
	F
	 	155oC
	 	105oC max (or 80oC)

ARMATURE WINDING INSULATION:

As standard armature voltages can vary from 220 up to 18,000 V, it is necessary to ensure the
appropriate amounts of turn-turn and turn-ground insulation used to withstand different situations,
such as steady state or transients. In low voltage systems the turn-turn insulation may be applied
directly to the conductor as a film. In higher voltages it is necessary special methods to prevent
corona effects.

Despite of this recommendation, WEG assures all equipment here manufactured use the same
treatment, which consists in Vacuum and Pressure Impregnation.

 

 

IMPREGNATION WITH VARNISH:

After winded both stator and rotor are submitted to deep vacuum varnish impregnation (VPI),
which fills completely all existing remaining gaps. We use polyester varnish, and it assures an
insulation class F (or superior) with temperature class of 155oC (337oF).

COOLING SYSTEM:

Heat generated by internal losses must be exhausted to keep the internal temperature stable and
under standard values. Usually heat is transferred directly to air and this air can either be
cooled in a closed circuit by an outside water or air-cooling system (indirectly cooling system) or
can be exhausted (directly cooled system). In the first case, a closed circuit, there is no
possibility of debris formation on the coils, as it may occur in the second case.

WEG manufactures generators for both applications with a protection degree of IP-23 (open) or
IP-54/55/65 (closed).

Stators are frequently cooled by blowing air over the coil ends and through radial channels in the
armature core. The channels are normally in the range of 6 up to 8mm wide, with spacing between
each other of about 50mm, but they may be omitted entirely on machines with short core lengths.

MECHANICAL COMPARISON BETWEEN SALIENT POLE AND PLAIN POLE ROTORS:

The field configuration, salient pole and plain pole rotors distinguish two fundamental variations
in the mechanical construction. In most but the smallest modern alternators and in some ac brush
less exciters, the field is the rotating element, and the armature is the stationary element
(stator). Salient pole construction, where the field windings are on pole pieces attached to a
rotor body, is used on slower speed machines, 1200 rpm and lower, because of it’s relatively lower
cost. Plain pole construction, where the field windings are inserted in axial slots in a
cylindrical rotor body, is used on essentially all 2 poles and on the larger 4 pole machines,
because it minimizes the problems of fitting salient poles to the rotor body, which in such
high-speed machines become non-practical and too risky. The fundamentals of stator core and
winding construction for these two types of design are the same, but as far as the mechanical
behaviour and life expectancy is concerned the plain pole cylindrical rotor is superior.

BEARINGS:

 

 

Smaller AC generators can be furnished with ball anti-friction bearings when the load and speed
are not critical and operate very well as long as a preventative maintenance program is followed.

However, the majority of the AC generators are supplied with oil-lubricated babbitted
bearings. For horizontal shafts these are self-contained ring-oiled bearings when design
conditions permit.

At higher shaft peripheral speeds and higher bearing loadings ring-oiling is supplemented with
forced circulation of external cooled oil. The rings may be replaced by an external source, such as
the same lubricating system used by the turbine, or WEG can supply a self-sustained lubrication
system.

Lead base babbitted bearings are commonly used for journal bearings, although tin-base babbitt may
be employed in heavy-duty applications.

All bearings have an electrical connection to the ground to isolate electrical currents.

SPACE HEATERS:

To avoid water condensing inside generator, this equipment is built with an electrical resistance
that can be powered from any typical 240 VAC outlet. This way it can be stored for a long time,
as long as the heater is on.

BALANCING:

The standard mechanical balancing adopted by WEG is stated by ISO 1940, which defines the possible
grades, N (Normal), R (reduced) or S (special). Our Quality Control does not allow any rotor to
continue in the manufacturing process chain if it reached a degree above R 2,5 (Reduced).

For this reason we can assure a long reliable life, and low bearing wear, as well as no vibration
is transmitted to other related machines.

COATING:

All generators have its internal and external surface treated with steel debris blasting until
it reaches the cleanness degree Sa 2.1/2.

First coating is applied using polyamide epoxy 35 – 40 microns thick.

Finishing consists into two polyamide epoxy coatings, each one 70-80 microns thick, with
standard colour Medium Blue RAL 5007.

 

 

The coating process is designed to allow the machine to be installed in regular-aggressive acid
atmosphere with good resistance to alkaloids and humidity, typical for Sugar — Alcohol
distilleries, Paper, Wood or related industrial processes, etc...

QUALITY INSPECTION:

All Manufactured generators are factory thoroughly tested. There is a standard testing
procedure, and it is completed with no exceptions.

Special tests can be performed with or without witness/inspection, but it should be agreed between
buyer and seller before the PO is placed so it can be scheduled in advance. Any changes after that
may affect final price, delivery time, and the chronology established when the unit is being
manufactured. Such chronology is very important due to the available time in the testing lab, as
all products are tested, and some of them have a specific deadline to be followed.

ELECTRONIC/MICROPROCESSED VOLTAGE REGULATOR:

The main purpose of the voltage regulator is to keep a steady output voltage at any load condition.
It may include functions such as allowing synchronization with other generators and/or power
utilities, allowing power factor correction, and allowing reactive power compensation throughout
the capability curve.

WEG uses an electronic and high-speed micro processed voltage regulator in order to assure such
flexible operation.

 

 

8. Summary of Supply

	 	§	 	TGM extraction/condensing steam turbine model TMCE 25000A for generator drive
	 
	 	§	 	Gearbox, parallel shafts, single stage, double helical type with tuning gear, s.f.= 1.3
	 
	 	§	 	High/Low speed couplings with coupling guards
	 
	 	§	 	Complete oil unit for turbine, gearbox and generator including mechanical oil pump, auxiliary lube oil
pump, emergency oil pump, twin oil filters, twin oil coolers, oil reservoir, and oil vapor extractor.
Provided on skid.
	 
	 	§	 	Common baseplate for turbine and gearbox
	 
	 	§	 	CPC (2) + Magnetic Pick-Ups (3)
	 
	 	§	 	Probes for vibration and axial displacement of the TG set (19) factory mounted and wired to junction box
	 
	 	§	 	Junction boxes and wiring to JB (not UL listed but meet NEMA standards)
	 
	 	§	 	UL listed instruments / motors where possible
	 
	 	§	 	Turbine / generator control panel including:
	 
	 	§	 	     Woodward 505 E governor
	 
	 	§	 	     Woodward Protech 203 overspeed protection
	 
	 	§	 	     Bently Nevada 3500 vibration system
	 
	 	§	 	     Allen Bradley ControlLogix with HMI
	 
	 	§	 	     Basler DEC 200
	 
	 	§	 	     GE SR-489 Multilin Generator Protection Relay
	 
	 	§	 	     Auto Synchronization
	 
	 	§	 	Transmitters with mounting rack
	 
	 	§	 	RTD’s factory mounted and wired to junction box
	 
	 	§	 	Painting according to TGM export plan
	 
	 	§	 	Manual steam drain valves
	 
	 	§	 	Visual indicators for returning lube oil from bearings
	 
	 	§	 	Weg TEWAC generator mounted on separate sole plate
	 
	 	§	 	Medium voltage switchgear including:
	 
	 	§	 	     Circuit breaker panel
	 
	 	§	 	     Neutral grounding resistor panel
	 
	 	§	 	     Surge protection panel
	 
	 	§	 	Starter, batteries and charger for DC emergency oil pump
	 
	 	§	 	Export packing for Brazilian equipment
	 
	 	§	 	Customs and port handling charges
	 
	 	§	 	Freight and insurance to job site
	 
	 	§	 	Shop tests to manufacturer’s standards. Third party inspections not included. (*)
	 
	 	§	 	Steam sealing system Field piping by others
	 
	 	§	 	Installation, start up, and training supervision (See conditions)
	 
	 	§	 	Acoustic hood for turbine and gearbox (option) (supplied loose)
	 
	 	§	 	Spare parts for 2 year operation (option)

 

			
	(*)	 	In case of external inspection, hired by the customer, TGM will evaluate impacts of
demands to its standard Inspections & Tests Plan. Relevant impacts such as costs and delivery
time will be charged to the customer.

 

 

8. Limits of supply

APP will limit its supply, as shown below:

Steam

	§	 	Inlet flange of the turbine emergency trip valve
	 
	§	 	Inlet flange of the gland steam sealing system
	 
	§	 	Exhaust flange of the turbine
	 
	§	 	Outlet flange of the turbine extraction
	 
	§	 	Inlet and outlet flanges of the extraction trip valve

Cooling water

	§	 	Inlet flange of the oil cooler
	 
	§	 	Outlet flange of the oil cooler
	 
	§	 	Inlet & outlet flange of generator water cooling section

Electricity

	§	 	Junction boxes terminals
	 
	§	 	Control panel terminals
	 
	§	 	Switchgear panel terminals

Drains

	§	 	Outlet flange of the drain valves

Air

	§	 	Inlet connections of the instruments/devices

OIL

	 	 	Supply & return connections of lube oil skid
	 
	 	 	Supply & return connections on turbine / gear basplate
	 
	 	 	Supply & return connections of generator bearings

 

 

9. Exclusions of Supply

	§	 	Steam, condensate and cooling water lines and accessories/instrumentation
(valves, supports, joints, insulation, condensate separator devices, etc...) out of
the limits of supply;
	 
	§	 	Civil works and foundation calculations;
	 
	§	 	Overhead crane;
	 
	§	 	Steam condenser and accessories/appurtenances;
	 
	§	 	Cooling water tower and water circulating pumps
	 
	§	 	Gland steam condenser, piping and accessories
	 
	§	 	Fire protection systems;
	 
	§	 	Electrical and mechanical interconnection out of the limits of supply;
	 
	§	 	Utilities such as electric energy, water, compressed air, welding materials and
others;
	 
	§	 	Flushing oil and first lube oil filling;
	 
	§	 	Stairways, scaffold, platforms and similar;
	 
	§	 	Safety and control valves out of the limits of supply
	 
	§	 	Anchor bolts set and leveler
	 
	§	 	Explosion proof instruments / accessories
	 
	§	 	Wiring between local junction boxes and control panel
	 
	§	 	Wiring between generator and switchgear panels
	 
	§	 	No-load running test
	 
	§	 	Performance test
	 
	§	 	Heat stability test
	 
	§	 	High speed balancing
	 
	§	 	Any special design, accessory and documentation (submittals) out of standard
scope of supply
	 
	§	 	Any other equipment not listed in this proposal

 

 

IEC Recommendations

45.19 Limiting values for steam pressure and temperature 

Pressure variations

Average steam pressure at turbine throttle during a 12 months period shall not exceed the
nominal pressure

Maintaining the average value, the steam pressure shall not exceed 5% of nominal pressure;
however instantaneous peak values up to 20% are allowed provided that the total duration of
peak loads shall not exceed 12 hours in a period of 12 months of operation.

Temperature variation

Temperature shall never exceed 8oC above the normal operating temperature. Under exceptional
circumstances the steam temperature can exceed 14oC above the operating temperature, provided that
these conditions do not exceed 400 hours in a period of 12 months of operation.

Steam line 

In order to assure a good performance of the turbine and prevent damages the steam conditions
shall remain within the limits stated above and the steam shall be free of condensate.

 

 

Condensate in the steam line may produce thermal shocks with severe consequences and
serious damages, for instance shaft distortion.

Specifications for lube oil in steam turbines

Mineral refined oil complying with the characteristics indicated by the DIN 51515 shall be
used for the regulation and lube system and must have de following characteristics:

	 	 	 	 	 
	Denomination	 	Requirement	 	Test according to
	Type of lube oil
	 	TD 68	 	 
	Viscosity class — ISO
	 	ISO VG 68	 	DIN 51519
	No (coordination)
	 	25	 	 
	Cinematic viscosity
	 	65,5 mm 2/s (cSt)	 	DIN 51550 together with,
	at 40oC
	 	8,7 mm 2/s (cSt)	 	DIN 51561 or DIN 51562
	at 100oC
	 	 	 	 
	Dynamic viscosity — average at 40oC
	 	65,5 x 10-3 Pas	 	 
	Viscosity index not less than
	 	95	 	 
	Density at 15oC not more than
	 	0,9 Kg/l	 	DIN 51757
	Ignition point as per Cleveland not less then
	 	200oC	 	DIN 51376

 

 

	 	 	 	 	 
	Denomination	 	Requirement	 	Test according to
	Pourpoint = or <
	 	-6oC	 	DIN 51597
	Neutralization index not to exceed
	 	(+) 0,1 mg KOH/g oil	 	DIN 51558 part I
	Saponification index not to exceed
	 	(+) 0,15mgKOH/g oil	 	DIN 51559
	Ashes (oxide) not to exceed
	 	(+) 0,01% w/w	 	 
	Water
	 	g/100g	 	DIN 51582
	Solid foreign matter below detectable levels
	 	g/100g	 	DIN 59592
	Water separation capacity (max)
	 	300 s	 	DIN 51589 part I
	Water separation capacity at 50oC (Max)
	 	5 min	 	DIN 51381
	Corrosion effect on copper — corrosion degree (Max)
	 	2....100 A3	 	DIN 51759 (3h up to 100oC)
	Corrosion protection (steel)
	 	0....A (corrosion free)	 	DIN 51585
	Neutralization index increase after 1000 h
	 	2,0 mg KOH/g oil	 	DIN 51587
	Capacity of specific load (gearbox)
	 	Normal test FZG	 	DIN 51354 (A/8, 3/90)
	 
	 	6-7 degree	 	ASTM D 1947-68
	 
	 	 	 	IP166/65

These values are valid only for mineral oil.

 

			
	(+)	 	When active substances are used the above values are higher.

Recommended quality for cooling water

The materials selection for steam condenser and heat exchanger is directly related to the type
of cooling water used (aggressiveness). It becomes clear that water aggressiveness in continuous
operation should not increase in relation to the value originally specified, because it may reduce
significantly the average lifetime of the equipment.

Besides, deposits on the tubes decrease the heat exchange efficiency and speed up internal
corrosions.

In order to assure safe operation, some basic requirements have to be followed, as indicated below:

Open circuit cooling

The total amount of salt shall not exceed 100 mg/l. Water shall have adequate chemical composition
because treatments are not applicable.

In case of particles in suspension, filtering must be applied. Seaweed can be eliminated by
clorification. To avoid separation of carbonates, it’s necessary to keep the balance of the
calcium/carbonic acid rate.

Closed circuit cooling

The following figures shall be kept:

 

 

	 	 	 

	PH
	 	7
	Carbonic acid
	 	3 g/l
	Carbonate hardness
	 	6°dH
	Carbonate hardness for polymorph phosphates
	 	12°dH
	Non-carbonate hardness
	 	80°dH
	Clorets
	 	400 mg/l
	Sulfates
	 	500 mg/l
	Total salt
	 	3000 mg/l
	Total alkalinity
	 	15 mgl/l
	Silic acid
	 	200 mg/l
	Particles in suspension
	 	10 mg/l

Note: Water flow shall be periodically inspected. The water chambers must be always clean.

 

 

APPENDIX D

	 	 	 	 	 

	SRS Engineering Standards Manual

	 	 	 	Manual: WSRC-TM-95-1
	Attachment 1

	 	Date: 9/13/07
	 	Page 1 of 7
	National Codes and Standards for Engineering/Design Tasks Matrix

	 	ENGINEERING STANDARDS BOARD
	 	Revision 17

	 	 	 	 	 

	Approved by:

	 	Ken Stevens, Signature on File	 	 
	 

	 	 

Chairman, Engineering Standards Board
	 	 

	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	GENERAL SERVICE	 	PRODUCTION	 	SAFETY	 	 
	APPLICATION	 	COMPONENT	 	See Note	 	SUPPORT	 	SIGNIFICANT	 	SAFETY CLASS
	ENVIRONMENTAL 

QUALIFICATIONS

	 	 	 	None
	 	 	 	 	 	IEEE-323
	 
	 	 	 	 	 	 	 	 	 	 
	SEISMIC 

QUALIFICATIONS	 	EQUIPMENT,

COMPONENTS	 	IBC
	 	Applicable national codes and standards are
listed in SRS Engineering Standard 01061 (if
seismic qualification is required)
	 
	 	 	 	 	 	 	 	 	 	 
	CHEMICAL &
TOXICOLOGICAL
HAZARDS	 	 	 	OSHA, AICHE Safety Standards, API Safety Standards, ACGIH Requirements, NEPA*
	 	 	 	 	N/A
	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	PRESSURE VESSELS, all services

as defined in the ASME BPV Code	 	ASME VIII-2004 Div. 1 or Div. 2 *	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	POWER BOILERS
	 	ASME I-2004*
	 	 	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	TRANSPORTATION PACKAGING
	 	49 CFR
	 	 	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	HEATING BOILERS
	 	ASME IV-2004*
	 	 	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	PROCESS EQUIPMENT 

VESSELS & TANKS

	 	FIBER-REINFORCED PLASTIC

PRESSURE VESSELS
	 	ASME X-2004*

API-12P
	 	 	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	STORAGE TANKS	 	API-620, ANSI/ASME B96.1 (Aluminum Alloy)*	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	WATER STORAGE TANKS
	 	AWWA D-100*
	 	 	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	PROCESS TANKS FOR
	 	API-620, API-650,
	 	 	 	API-650 and NFPA-30	 	 
	 	 	FLAMMABLE LIQUIDS	 	UL-142 (above ground), NFPA 30, NFPA 326	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	PETROLEUM STORAGE TANKS
	 	API-650*
	 	 	 	API-650	 	 
	 	 	 	 	UL-58 and UL-1316 (under ground)	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	CHEMICAL PROCESS PUMPS	 	ANSI/ASME B73, 1M & 2M, Hydraulic Institute Standards*	 	 
	 	 	 	 	API-674, API-675, ASME B73.5M N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	PROCESS EQUIPMENT 

PUMPS	 	POTABLE & SANITARY WATER
PUMPS	 	AWWA E101*	 	 	 	This standard has been withdrawn
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	FUEL OIL SERVICES PUMPS
	 	API-610*
	 	 	 	No, N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	OTHER PROCESS SERVICE

PUMPS	 	Hydraulic Institute Standards, API, ASME *	 	No	 	 

 

			
	*	 	Codes and standards listed in the lower classifications are also requirements for the higher
classifications. Where requirements in the lower classifications conflict with requirements in the
higher classifications, the more restrictive requirement governs.

 

 

	 	 	 	 	 

	SRS Engineering Standards Manual

	 	 	 	Manual: WSRC-TM-95-1
	Attachment 1

	 	Date: 9/13/07
	 	Page 2 of 7
	National Codes and Standards for Engineering/Design Tasks Matrix

	 	ENGINEERING STANDARDS BOARD
	 	Revision 17

	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	GENERAL SERVICE	 	PRODUCTION	 	SAFETY	 	 
	APPLICATION	 	COMPONENT	 	See Note	 	SUPPORT	 	SIGNIFICANT	 	SAFETY CLASS
	 

	 	POWER SYSTEMS

(PIPING & VALVES)
	 	ASME B31.1-2001*
	 	Yes	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	PROCESS SYSTEMS

(PIPING & VALVES)	 	ASME B31.3-2002

and B31.3 is for process	 	No – using B31.1 since it is applicable to power plants
	 	 	 	 	Clarification in the application of these codes and standards is provided in SRS Engineering Standard 15060 (WSRC-TM-95-1)
	 

	 	 	 	 	 	No	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	PIPING & VALVES

	 	BUILDING SERVICES

(PIPING & VALVES)
	 	ASME B31.3-2002 or B31.9-2004*
	 	No	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	WATER DISTRIBUTION SERVICES
(PIPING & VALVES)	 	AWWA C Series*	 	No — using International Plumbing Code
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	REFRIGERATION PIPING
	 	ASME B31.3-2002 or B31.5-2001
	 	N/A	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	OTHER BASIC CODES &
	 	AWWA*
	 	No	 	 	 	 
	 	 	STANDARDS	 	API, ASME I-2004	 	No and Yes as applicable
	 

	 	(PIPING & VALVES)
	 	ASME B31.5-2001
	 	N/A	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	PLUMBING

	 	PLUMBING SYSTEMS

in infra-structure facilities
	 	International Plumbing Coe (IPC) *
	 	Yes	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	PROCESS EQUIPMENT 

GENERAL

	 	MOISTURE SEPARATORS

OIL LUBRICATORS
	 	ANSI/B93.114M (restricted use
of nonmetallic bowls)*
	 	 	 	N/A, see comment	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	GLOVE BOXES	 	 	 	NFPA 801, NFPA 45, NFPA 69, AGS-G001-1998*	 	 	 	 
	 	 	 	 	AGS-G003-1998, ANSI/ASTM C852	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	STRUCTURAL	 	GENERAL DESIGN	 	Applicable national codes and standards are listed in SRS Engineering Standard 01060.     No — IBC
	 
	 	 	 	 	 	 	 	 	 	 
	CIVIL	 	GENERAL DESIGN	 	Applicable national codes and standards are listed in SRS Engineering Standard 01060.     No – IBC
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	SURVEYING	 	FGDC-STD-007.4 (Federal Geographic Data Committee)	 	No	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	GENERAL DESIGN	 	OSHA, NFPA 101, 220 & 221,
NRCA*	 	 Yes – International Building Code & International Fire Code
	 
	 	 	 	 	 	 	 	 	 	 
	ARCHITECTURAL	 	PHYSICALLY HANDICAPPED	 	UFAS*	 	No, except on administration building
	 
	 

	 	BUILDING CODE
	 	International Building Code (IBC)*
	 	Yes	 	 	 	 

 

			
	*	 	Codes and standards listed in the lower classifications are also requirements for the higher
classifications. Where requirements in the lower classifications conflict with requirements in the
higher classifications, the more restrictive requirement governs.

 

 

	 	 	 	 	 

	SRS Engineering Standards Manual

	 	 	 	Manual: WSRC-TM-95-1
	Attachment 1

	 	Date: 9/13/07
	 	Page 3 of 7
	National Codes and Standards for Engineering/Design Tasks Matrix

	 	ENGINEERING STANDARDS BOARD
	 	Revision 17

	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	GENERAL SERVICE	 	PRODUCTION	 	SAFETY	 	 
	APPLICATION	 	COMPONENT	 	See Note	 	SUPPORT	 	SIGNIFICANT	 	SAFETY CLASS
	MECHANICAL HANDLING	 	CRANES	 	ASE NOG-1	 	 	 	 
	EQUIPMENT	 	 	 	CMAA 70, CMAA 74, CMAA III-5, 11, 12 and 17; ASME B30.2, B30.11* No
	 
	 

	 	OTHER HANDLING EQUIPMENT
	 	AISC*
ANSI N14.6
	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	GENERAL FIRE PROTECTION	 	NFPA Fire Codes and Standards, Building Code (IBC), Uniform Fire Code, 29-CFR-1910
	 	 	 	 	For exceptions to these codes and standards refer to Standard 01120, Attachment 1* 	Yes
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	AUTOMATIC SPRINKLER	 	NFPA 13, 15, 25, 72, Building Code (IBC)*	 	Yes	 	 
	 

	 	SYSTEMS	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	WATER MIST SYSTEMS	 	NFPA 72, 750, Building Code (IBC)*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	STANDPIPE SYSTEMS	 	NFPA 14, Building Code (IBC)*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	FOAM SYSTEMS	 	NFPA 11, 11A, 16, 18, Building Code (IBC)*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	FIRE PUMPS	 	NFPA 20, 25, 30, 70-2005, 72, Building Code (IBC)*	 	 	 	Yes
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	WATER SUPPLIES	 	NFPA 13, 20, 22, 24 291, 1142, Building Code (IBC)*	 	1142 does not apply	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	WATER DISTRIBUTION AND FIRE	 	NFPA 24, 25, 1141, 1963, Building Code (IBC)*	 	Yes	 	 
	 

	 	HOSE	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	LIQUID RUN-OFF CONTROL	 	NFPA 30, 70-2005, 801, Building Code (IBC)*	 	801 does not apply. Additional, 850 will be used
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	GASEOUS FIRE SUPPRESSION	 	NFPA 12, 2001, Building Code (IBC)*	 	Yes	 	 
	 

	 	SYSTEMS	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	FIRE PROTECTION SYSTEMS	 	CHEMICAL FIRE SUPPRESSION	 	NFPA 17, 17A, 72, 96, Building Code (IBC)*	 	96 does not apply
	 
	 

	 	FIRE ALARM & DETECTION
	 	NFPA 70-2005, 72, 90A,
101, 170, 801, UL 268A, Building Code (IBC)* not apply
	 	 	 	No to UL 268A, 801 does
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	LIFE SAFETY	 	NFPA 70-2005, 101, 110, 111, Building Code (IBC)*	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	FIRE EXTINGUISERS	 	29-CFR-1910.57, NFPA 10, 30, 51B, 95, Building Code (IBC)*	 	 	 	Yes
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	CONSTRUCTION SITES	 	29-CFR-1926 SubPart F, NFPA 1, 241, Building Code (IBC)*	 	 	 	Yes
	 
	 	 	PERMANENT STRUCTURES	 	NFPA 220, Building Code (IBC)*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	TEMPORARY BUILDINGS	 	Building Code (IBC)*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	FIRE EXPOSURE PROTECTION	 	NFPA 1, 80a, 1144, Building Code (IBC)*	 	1142 does not apply
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	VENTILATION SYSTEMS	 	NFPA 90A, 90B, 91, 92A, 204M, 601, UL 586, UL 900, Building Code (IBC)*	 	No to UL 586 & UL 900
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	FIRE RATED CONSTRUCTION	 	NFPA 80A, 90A, 101, 220, 221, Building Code (IBC)*	 	 	 	 
	 	 	 	 	Building Code (IBC) (Area Separation)	 	 	 	 
	 	 	 	 	Building Code (IBC) (Occupation Separation)	 	Yes	 	 
	 	 	 	 	NFPA 80	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	STRUCTURAL DESIGN	 	NFPA 220, Building Code (IBC)*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	CABLE INSTALLATIONS	 	NFPA 13, 70-2005, 70B, 70E-2004, 262, Building Code (IBC)*	 	 	 	Yes
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	COOLING TOWERS	 	NFPA 214, Building Code (IBC)*	 	Yes	 	 

 

			
	*	 	Codes and standards listed in the lower classifications are also requirements for the higher
classifications. Where requirements in the lower classifications conflict with requirements in the
higher classifications, the more restrictive requirement governs.

 

 

	 	 	 	 	 

	SRS Engineering Standards Manual

	 	 	 	Manual: WSRC-TM-95-1
	Attachment 1

	 	Date: 9/13/07
	 	Page 4 of 7
	National Codes and Standards for Engineering/Design Tasks Matrix

	 	ENGINEERING STANDARDS BOARD
	 	Revision 17

	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	GENERAL SERVICE	 	PRODUCTION	 	SAFETY	 	 
	APPLICATION	 	COMPONENT	 	See Note	 	SUPPORT	 	SIGNIFICANT	 	SAFETY CLASS
	 	 	ELECTRONIC COMPUTER/DATA PROCESSING SYSTEMS	 	NFPA 75*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	ELECTRICAL TRANSFORMERS	 	NFPA 70-2005, Building Code (IBC)*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	EXPLOSIVES	 	NFPA 68,69, 70-2005, 495, 498, 780, Building Code (IBC)	 	ATF 5400	 	 
	 	 	 	 	27-CFR, Parts 55 & 181 49-CFR, Parts 100 to 199	 	Title 18 USC 40*	 	N/A
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	GLOVEBOXES, HOT CELLS, HOODS AND CANYONS	 	NFPA 45, 69, 90A, 91, 801 Building Code (IBC)*	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	HAZARDOUS MATERIALS	 	NFPA 30, 30B, 55, 58, 59A, 704, 801, Building Code (IBC)*	 	30B, 58, 59A & 801 does not apply
	 
	 	 	 	 	 	 	 	 	 	 
	FIRE PROTECTION SYSTEMS	 	LABORATORIES	 	NFPA 45, 801, Building Code (IBC)*	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	LASERS	 	NFPA 70-2005, 79, 115, 21-CFR 1040,
ANSI Z136.1-2000*	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	PRYOPHORIC MATERIALS &
COMBUSTIBLE METALS	 	NFPA 68, 69, 480, 481, 482, 651, 801, Building Code (IBC)*	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	Record Storage	 	NFPA 232*	 	Yes	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	ABANDONED, SHUTDOWN, or DEACTIVATED BUILDINGS	 	Abandoned Facilities & Facilities undergoing D&D
NFPA 801	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	FIRE SYSTEM TESTING	 	Per NFPA installation codes and standards
except as revised in the S/RIDs
NFPA 25 & 72	 	Per NFPA installation codes and standards unless
permitted by AB documents to allow S/RIDs
modified test frequencies
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	NFPA 37, 70-2005,
70E-2004, 101, 110, 111, 708 & 496	 	IEEE-577*	 	IEEE-308, 336, 338

IEEE-379, 384, 603
	 	 	 	 	ANSI/IEEE-C2, NEMA-C84.1, NEMA ICS
ASHRAE-90	 	 	 	 
	 	 	SYSTEM DESIGN	 	IES Lighting Handbook	 	 	 	 
	ELECTRICAL SYSTEMS	 	 	 	IEEE Series C37, C57, C62	 	 	 	 
	 	 	 	 	IEEE-141, 242, 739, 399, 446, 450, 484, 485, 493	 	NFPA Only	 	 
	 	 	 	 	IEEE-1015	 	 	 	 
	 	 	 	 	UL-508, 96 & 96A*	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 	 	GROUNDING & LIGHTNING
PROTECTION	 	ANSI/IEEE-C2, NFPA 70-2005, 780
IEEE-80, IEEE-142, IEEE-1050, IEEE-1100*	 	NFPA Only	 	 

 

			
	*	 	Codes and standards listed in the lower classifications are also requirements for the higher
classifications. Where requirements in the lower classifications conflict with requirements in the
higher classifications, the more restrictive requirement governs.

 

	 	 	 	 	 

	SRS Engineering Standards Manual

	 	 	 	Manual: WSRC-TM-95-1
	Attachment 1

	 	Date: 9/13/07
	 	Page 5 of 7
	National Codes and Standards for Engineering/Design Tasks Matrix

	 	ENGINEERING STANDARDS BOARD
	 	Revision 17

	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	GENERAL SERVICE	 	PRODUCTION	 	SAFETY	 	 
	APPLICATION	 	COMPONENT	 	See Note	 	SUPPORT	 	SIGNIFICANT	 	SAFETY CLASS
	 	 	AIR FLOW & CONTROL	 	S 29 CFR 1910 Subparts G & H*	 	 
	 	 	 	 	NFPA 90A, 90B & 91	 	As required by IFC & International Mechanical Code
	 
	 

	 	AIR HEATERS
	 	Industry Standards*
	 	 	 	 	 	ASME AG-1
	 	 	 	 	NFPA           As required by IFC & International Mechanical Code	 	 
	 
	 	 	AIR HANDLING UNITS

(HVAC only)	 	ARI 430*        As required by IFC & International Mechanical Code	 	ASME AG-1
	 
	 	 	FILTER HOUSINGS

(NATS only)	 	ASME N509*        As required by IFC & International Mechanical Code	 	ASME AG-1
	 
	HVAC EQUIPMENT	 	DAMPERS	 	SMACNA Standards, ASME N509, NFPA 90A, UL 555 & 555S	 	ASME AG-1
	and	 	 	 	NFPA 801 (NATS only)*         As required by IFC & Inter Mechanical Code	 	 
	 
	NUCLEAR AIR	 	DUCTWORK	 	SMACNA Standards*         As required by IFC & International Mechanical Code	 	 
	TREATMENT	 	FANS	 	AMCA*            As required by IFC & International Mechanical Code	 
	SYSTEMS
	 	 	 	 	 	 	 	 	 	 
	(NATS) EQUIPMENT

(Installed in Nuclear 

Facilities)	 	FILTERS	 	ASHRAE (HVAC only), ASME N509* 

The use of ASME AG-1 is required for all HEPA
filters that fall within the requirements of
Engineering Standard 15888	 	ASME AG-1
As required
by IFC & International
 Mechanical Code 	 	
	 
	 

	 	ADSORBERS

(NATS only)
	 	ASME N509*
	 	N/A
	 	 	 	ASME AG-1
	 
	 	 	DUCT INSULATION	 	ASHRAE Fundamentals Handbook, Chapter 26, “insulation of Mechanical Systems”	 	 
	 	 	 	 	As required by IFC & International Mechanical Code	 	 
	 
	 

	 	REFRIGERATION UNITS

	 	ARI 450*
	 	N/A
	 	 	 	ASME AG-1
	 
	 

	 	(HVAC only)
COILS
	 	ARI 410*
	 	N/A
	 	 	 	ASME AG-1

 

			
	*	 	Codes and standards listed in the lower classifications are also requirements for the higher
classifications. Where requirements in the lower classifications conflict with requirements in the
higher classifications, the more restrictive requirement governs.

 

 

	 	 	 	 	 

	SRS Engineering Standards Manual

	 	 	 	Manual: WSRC-TM-95-1
	Attachment 1

	 	Date: 9/13/07
	 	Page 6 of 7
	National Codes and Standards for Engineering/Design Tasks Matrix

	 	ENGINEERING STANDARDS BOARD
	 	Revision 17

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	GENERAL SERVICE	 	PRODUCTION	 	SAFETY	 	 
	APPLICATION	 	COMPONENT	 	See Note	 	SUPPORT	 	SIGNIFICANT	 	SAFETY CLASS
	 	 	COATINGS  	 	SSPC for above ground steel *	 	No to NACE
	 	 	 	 	 	 	NACE for concrete & underground steel	 	 
	 
	 	 	NDE  	 	ASME V-2004, ASNT, ASME B31.1-2001, B31.3-2002, B&PV Code-2004, *	 	 AMSE V, ASME B31.1 and AWS
	 	 	 	 	 	 	API, AWS, AWWA, ASTM Volume 03.03	 	 
	 
	MATERIALS	 	GASKETS, PACKAGING, etc.	 	ANSI B16.5, B1620, B16.21, DIN 3535 Part 4	 	 
		 		 	ASTM D149, D792, D1708, D2000, F36, F37B, F38, F104, F146, F152, F433	 	 
	 	 	 	 	 	 	ASME Section VIII-2004 Div. 1 for “m” and “y” data *	 	Yes
	 
	 	 	CORROSION EVALUATION	 	ASTM A262, A763, G28, NACE *	 	No
	 
	 	 	INSULATION	 	For materials specification & testing — ASTM Volume 04.06	 	Yes
	 	 	 	 	 	 	For selection & application – None	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	 	 	MATERIAL	 	 	 	 	 	 
	 	 	 	 	Steel	 	AWS D1.1, (Alternate ASME Section IX-2004) *	 	Yes
	 	 	STRUCTURAL	 	Aluminum	 	AWS D1.2, (Alternate ASME Section IX-2004) *	 	Yes
	 	 	 	 	Sheet Steel	 	AWS D1.3, (Alternate ASME Section IX-2004) *	 	Yes
	 	 	 	 	Stainless Steel	 	AWS D1.6, (Alternate ASME Section IX-2004) *	 	Yes
	 
	 	 	HVAC	 	MATERIAL	 	AWS D9.1, (Alternate ASME Section IX-2004) *	 	Yes
	 

	 	 	 	Sheet Metal	 	 	 	 	 	 
	 
	 

	 	 	 	METALLIC	 	 	 	 	 	 
	MATERIALS	 	 	 	Power	 	ASME B31.1-2001 *	 	Yes
	WELDING & JOINING

	 	 	 	Process
	 	ASME B31.3-2002, (also see Standard 15060) *
	 	No – B31.1
	 	 	PIPING	 	Refrigeration	 	ASME B31.5-2001 or B31.3-2002 *	 	N/A
	 

	 	 	 	Bldg Services
	 	ASME B31.9-2004 or B31.3-2002 *
	 	 	 	No– B31.1
	 	 	 	 	Fire Protection	 	NFPA, ASME B31.1-2001 *	 	Yes
	 	 	 	 	Non-Metallic	 	ASME B31.3-2002 (also see Standard 15060) *	 	Yes
	 	 	 	 	Copper-Solder	 	Copper Tube Handbook *	 	No
	 
	 	 	PRESSURE VESSELS	 	ASME Section VIII-2004, ASME Section I-2004 *	 	Yes
	 
	 	 	TANKS	 	API, ASME *	 	Yes
	 
	 	 	WELDING SAFETY	 	ANSI Z49.1-2005 *	 	Yes

 

			
	*	 	Codes and standards listed in the lower classifications are also requirements for the higher
classifications. Where requirements in the lower classifications conflict with requirements in the
higher classifications, the more restrictive requirement governs.

 

 

	 	 	 	 	 

	SRS Engineering Standards Manual

	 	 	 	Manual: WSRC-TM-95-1
	Attachment 1

	 	Date: 9/13/07
	 	Page 7 of 7
	National Codes and Standards for Engineering/Design Tasks Matrix

	 	ENGINEERING STANDARDS BOARD
	 	Revision 17

	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	GENERAL SERVICE	 	PRODUCTION	 	SAFETY	 	 
	APPLICATION	 	COMPONENT	 	See Note	 	SUPPORT	 	SIGNIFICANT	 	SAFETY CLASS
	TELECOMMUNICATIONS
SYSTEMS	 	PATHWAYS AND SPACES	 	ANSI/TIA/EIA — 569-B, ANSI/TIA/EIA-758-A, TIA/EIA-222-F *

NFPA 70-2005 (NEC), NFPA 76, ANSI/IEEE C-2 (NESC)
	 	N/A
	 	 	
For exceptions/deviations to these standards/codes, see Telecommunications Std 16055, Section 3.3
	 
	 	COMMERCIAL BUILDING WIRING	 	ANSI/TIA/EIA-568-B.1 thru B.3.1, ANSI/TIA/EIA-598-B, ANSI/TIA/EIA-526-7 and 526-14A *

ANSI/TIA/EIA-758-A, NFPA 70-2005 (NEC), ANSI/IEEE C-2 (NESC)

	 	N/A
	 	 	
For exceptions/deviations to these standards/codes, see Telecommunications Std 16055, Section 3.3
	 
	 	GROUNDING AND BONDING

REQUIREMENTS	 	ANSI-J-STD-607-A *

NFPA 70-20005 (NEC), ANSI/IEEE C-2 (NESC)

	 	N/A
	 	 	
For exceptions/deviations to these standards/codes, see Telecommunications Std 16055, Section 3.3
	 
	 	 	 	 	 	 	 	 	 	 
	 

	 	GENERAL DESIGN
	 	ISA-S5.1, S5.3

ANSI N323 *
	 	ISA
	 	Applicable standards
are listed in WSRC
Eng. Std 01703
	 	IEEE-323, 336, 338

IEEE-379, 384
	INSTRUMENTATION

&
 CONTROLS

	 	SETPOINTS & SCALING
	 	None
	 	 	 	ISA-S67.04 *
	 	MONITORING
	 	HPS-N13.1, ANSI-N42.18, NFPA 

70-2005 *
	 	ANS 8.3 (Nuclear
criticality only)
	 	ANSI-N320
	 	 	 	 	 	NFPA	 	 	 	 
	 

	 	PROGRAMMABLE DIGITAL

EQUIPMENT

GENERAL DESIGN
	 	 	 	 	 	Applicable standards
are listed in WSRC
Eng. Std 01703	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	HUMAN FACTORS 

ENGINEERING

	 	GENERAL DESIGN
	 	IEEE-1023, IEEE-845, NUREG-0700 *
	 	N/A	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	EXPLOSIVES 

SAFETY

	 	GENERAL DESIGN
	 	DOE Manual 440.1-1A,
1/9/2006 * 

NFPA 69 & 495
	 	N/A	 	 

Note: There are a number of codes and standards listed in the matrix with a specific revision
date (e.g. NFPA 70-2005). When a Design Authority or Design
Agency wants to use a later revision (successor) of a code or standard that is listed by a specific
date, they must first perform an engineering evaluation per
WSRC-TM-95-1, Responsibilities and Requirements.

 

			
	*	 	Codes and standards listed in the lower classifications are also requirements for the higher
classifications. Where requirements in the lower classifications conflict with requirements in the
higher classifications, the more restrictive requirement governs.

 

APPENDIX E

Project Schedule

Note: Appendix E to be provided upon contract award.

 

 

APPENDIX F

A total of 141 pages were omitted and filed separately with the Securities and Exchange Commission
pursuant to a request for confidential treatment.

 

			
	[**] 	 	

 

 

APPENDIX G

A total of 46 pages were omitted and filed separately with the Securities and Exchange Commission
pursuant to a request for confidential treatment.

 

			
	[**]exv10w3

Exhibit 10.3

LEAR CORPORATION

OUTSIDE DIRECTORS COMPENSATION PLAN

As Amended and Restated Effective January 1, 2010

 

 

LEAR CORPORATION

OUTSIDE DIRECTORS COMPENSATION PLAN

Article 1. Establishment, Objectives and Duration

     1.1 Amendment and Restatement of Plan. Lear Corporation, a Delaware corporation, hereby
amends and restates the compensation plan for non-employee directors known as the “Lear Corporation
Outside Directors Compensation Plan” (hereinafter referred to as the “Plan”), as set forth
in this document.

     1.2 Plan Objectives. The objectives of the Plan are to give the Company an advantage in
attracting and retaining Outside Directors and to link the interests of Outside Directors to those
of the Company’s stockholders.

     1.3 Duration of the Plan. The Plan commenced on January 1, 2004 and will remain in effect
until the Board of Directors terminates it pursuant to Section 9.1.

Article 2. Definitions

     The following defined terms have the meanings set forth below:

     “Account” means a notional account in the Outside Director’s name to which compensation not
immediately payable to him or her and, if applicable, interest earned thereon, is credited.

     “Affiliate” means any person that, directly or indirectly, is in control of, is controlled by,
or is under common control with, the Company.

     “Annual Retainer” means the retainer fee established by the Board in accordance with Section
5.1 and paid to an Outside Director for services performed as a member of the Board of Directors
for a Plan Year.

     “Beneficiary” means the person entitled under Section 6.5 to receive payment of the balances
remaining in an Outside Director’s Account in case the Outside Director dies before the entire
balance in that Account has been paid.

     “Board” or “Board of Directors” means the Board of Directors of the Company.

     “Change in Control” of the Company will be deemed to have occurred (as of a particular day, as
specified by the Board) as of the first day any one or more of the following paragraphs is
satisfied.

     (a) Any Person (other than the Company or a trustee or other fiduciary holding securities
under an employee benefit plan of the Company, or a corporation owned directly or

2

 

indirectly by the shareholders of the Company in substantially the same proportions as their
ownership of stock of the Company) becomes the Beneficial Owner, directly or indirectly, of
securities of the Company, representing more than twenty percent of the combined voting power of
the Company’s then outstanding securities.

     (b) During any period of twenty-six consecutive months beginning on or after the Effective
Date, individuals who at the beginning of the period constituted the Board cease for any reason
(other than death, Disability or voluntary Retirement) to constitute a majority of the Board. For
this purpose, any new Director whose election by the Board, or nomination for election by the
Company’s shareholders, was approved by a vote of at least two-thirds of the Directors then still
in office, and who either were Directors at the beginning of the period or whose election or
nomination for election was so approved, will be deemed to have been a Director at the beginning of
any twenty-six month period under consideration.

     (c) Consummation of: (i) an agreement for the sale or disposition of all or substantially all
the Company’s assets; or (ii) a merger, consolidation or reorganization of the Company with or
involving any other corporation, other than a merger, consolidation or reorganization that results
in the voting securities of the Company outstanding immediately prior thereto continuing to
represent (either by remaining outstanding or by being converted into voting securities of the
surviving entity) at least fifty percent of the combined voting power of the voting securities of
the Company (or such surviving entity) outstanding immediately after such merger, consolidation, or
reorganization.

     (d) The shareholders of the Company approve a plan of complete liquidation or dissolution of
the Company.

     Notwithstanding the foregoing, if an amount is “deferred compensation” for purposes of Code
Section 409A, and if payment of such amount would be accelerated or otherwise triggered upon a
“Change in Control,” then the foregoing definition is modified, to the extent necessary to avoid
the imposition of an excise tax under Code Section 409A, to mean a “change in control event” as
such term is defined for purposes of Code Section 409A. For purposes of clarity, if an amount
would, for example, vest and be paid on a “Change in Control” as defined herein but payment of such
amount would violate the provisions of Code Section 409A, then the amount shall vest but will be
paid only in compliance with its terms and Code Section 409A (i.e., upon a permissible payment
event).

     “Code” means the Internal Revenue Code of 1986, as amended from time to time, or any successor
to it.

     “Committee Meeting Fee” means the fee established by the Board in accordance with Section 5.1
and paid to an Outside Director for each attendance at a meeting of a Board committee (including
telephonic meetings but excluding execution of unanimous written consents).

3

 

     “Common Stock Fair Market Value” means the average of the high and low prices of publicly
traded Shares on the national exchange on which the Shares are listed as of a particular date.

     “Company” means Lear Corporation, a Delaware corporation, and any successor thereto as
provided in Section 9.3.

     “Deferral Election” has the meaning ascribed to it in Section 6.1.

     “Director” means any individual who is a member of the Board of Directors.

     “Disability” means the individual is unable to engage in any substantial gainful activity by
reason of any medically determinable physical or mental impairment which can be expected to result
in death or can be expected to last for a continuous period of not less than 12 months.

     “Effective Date” has the meaning ascribed to it in Section 8.1.

     “Exchange Act” means the Securities Exchange Act of 1934, as amended from time to time, or any
successor to it.

     “Grandfathered Account” means the portion of an Account attributable to compensation that was
deferred and vested as of December 31, 2004.

     “Installment Payment” has the meaning ascribed to it in Section 5.1.

     “Meeting Fee” means the fee established by the Board in accordance with Section 5.1 and paid
to an Outside Director for each attendance at a meeting of the Board of Directors (including
telephonic meetings but excluding execution of unanimous written consents).

     “Nongrandfathered Account” means the portion of an Account that is not a Grandfathered
Account.

     “Outside Director” means a Director who, at the time in question, is not an employee of the
Company or any of its Affiliates.

     “Plan” has the meaning ascribed to it in Section 1.1.

     “Plan Year” means the 12 month period beginning on January 1 and ending on the next following
December 31.

     “Plan Year Account” for a given Plan Year means the portion of a Participant’s Account
attributable to compensation deferred for such Plan Year.

     “Presiding Director” means the Outside Director selected by the other Outside Directors as the
presiding Director at meetings of the Outside Directors held in accordance with applicable rules of
any securities exchange on which the Company’s securities are listed.

4

 

     “Restricted Grant” means a grant made pursuant to Section 5.2 that is subject to vesting and
other restrictions as set forth in Article 7.

     “Retirement” means a Separation from Service (a) upon or after attaining 70 years of age, or
(b) upon or after serving six years as a Director, or (c) upon such other circumstances that the
Board, in its sole discretion, affirmatively determines not to be adverse to the best interests of
the Company.

     “Separation from Service” or “Separate from Service” means ceasing to be a Director of the
Company for any reason. Notwithstanding anything to the contrary, the determination of whether an
individual has had a Separation from Service will be made in accordance with Code Section 409A and
the regulations thereunder.

     “Shares” means the shares of common stock, $.01 par value, of the Company, including their
associated preferred share purchase rights.

     “Termination Date” means the date on which an Outside Director has a Separation from Service.

Article 3. Administration

     3.1 The Board of Directors. The Plan will be administered by the Board of Directors. The
Board of Directors will act by a majority of its members at the time in office and eligible to vote
on any particular matter, and may act either by a vote at a meeting or in writing without a
meeting.

     3.2 Authority of the Board of Directors. Except as limited by law and subject to the
provisions herein, the Board of Directors has full power to: construe and interpret the Plan and
any agreement or instrument entered into under the Plan; establish, amend or waive rules and
regulations for the Plan’s administration; and amend the terms and conditions of the Plan.
Further, the Board of Directors will make all other determinations which may be necessary or
advisable for the administration of the Plan. As permitted by law and consistent with Section 3.1,
the Board of Directors may delegate some or all of its authority under this Plan.

     3.3 Decisions Binding. All determinations and decisions made by the Board of Directors
pursuant to the provisions of the Plan will be final, conclusive and binding on all persons,
including the Company, its stockholders, all Affiliates, Outside Directors and their estates and
beneficiaries.

Article 4. Eligibility

     Each Outside Director of the Board during a Plan Year will participate in the Plan for that
year.

Article 5. Annual Retainer and Stock Grant

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     5.1 Amount Payable in Cash. Each Outside Director will be entitled to receive an Annual
Retainer in the amount determined from time to time by the Board. Until changed by resolution of
the Board of Directors, the Annual Retainer will be $110,000 for each Outside Director, provided
that the Annual Retainer for the Presiding Director will be increased by $10,000. In addition, the
Annual Retainer for the chair of the Audit Committee will be increased by $20,000 and the Annual
Retainer for the chair of each of the following committees will be increased by $10,000:
Compensation Committee and Nominating and Corporate Governance Committee.

     To the extent the Outside Director has not made a Deferral Election with respect to the Annual
Retainer, it will be paid in monthly cash installments (the “Installment Payments”) to the
Outside Director, payable on the last business day of the month preceding the month to which the
installment applies. Each Installment Payment to an Outside Director will equal the quotient of
the Outside Director’s Annual Retainer divided by twelve. Any Outside Director who first becomes
an Outside Director during a calendar month will be entitled to an Installment Payment for that
month unless, immediately before becoming an Outside Director, he or she was a Director who was an
employee of the Company or any of its Affiliates. Notwithstanding the foregoing, with respect to
any Outside Director who was a participant in the Plan as of January 29, 2010, a portion of the
Annual Retainer equal to $24,000 for each of the Plan Years 2010, 2011 and 2012, will be treated as
a Restricted Grant pursuant to Section 5.3 and paid according to Article 7.

     No Meeting Fees shall be paid with respect to the first twelve meetings of the Board attended
by an Outside Director in any Plan Year. Each Outside Director will be entitled to receive a
Meeting Fee, in the amount determined from time to time by the Board, for each meeting of the Board
he or she attends that is in excess of twelve meetings within a Plan Year (including telephonic
meetings but excluding execution of unanimous written consents). Until changed by resolution of
the Board of Directors, the Meeting Fee will be $1,500. Unless the Outside Director has made a
Deferral Election with respect to them, Meeting Fees, if any, will be paid on the last business day
of the month in which the meeting was attended (at the same time as the Installment Payment for the
next month). No Meeting Fees shall be paid with respect to meetings of any standing committee of
the Board (e.g., Audit Committee, Compensation Committee and Nominating and Corporate Governance
Committee) attended by an Outside Director. Committee Meeting Fees for meetings of any special
committee of the Board will be established at the time the Board establishes such committee.

     5.2 Stock Grant. Each Outside Director will be entitled to receive an unrestricted grant of
Shares, which grant will be made under the 2009 Lear Corporation Long-Term Stock Incentive Plan, or
a successor plan, as of the Effective Date (for Plan Year 2010) and as of the date of any annual
meeting of the stockholders of the Company at which such Outside Director is elected or re-elected
to serve in such position (for Plan Year 2011 and thereafter). The amount of the unrestricted
stock grant will be determined from time to time by the Board. Until changed by resolution of the
Board of Directors, the number of Shares subject to each unrestricted stock grant for each Outside
Director will be equal to $130,000 divided by the Common Stock Fair Market Value on the date of the
grant. The unrestricted grant of Shares shall be deemed earned

6

 

upon the date of grant and shall not be subject to forfeiture, in whole or in part, in the
event an Outside Director ceases to be an Outside Director for any reason, including resignation or
removal (with or without cause).

     5.3 Restricted Grant. Each Outside Director who was an Outside Director on January 29, 2010,
shall be treated as receiving a Restricted Grant in the amount of $72,000 on that date. This
amount shall be paid according to Article 7, in lieu of a portion equal to $24,000 of the Annual
Retainer such Outside Director would otherwise receive for services in each of the Plan Years 2010,
2011, and 2012. No Restricted Grants shall be made after January 29, 2010.

Article 6. Deferral

     6.1 Deferral Election. Any Outside Director may elect to defer all or a portion of the
compensation payable to him or her under Section 5.1 for the Plan Year by filing with the Secretary
of the Company a written notice to that effect (a “Deferral Election”), on a form provided
by the Company. A Deferral Election must be filed before the first day of the Plan Year to which
it relates. Notwithstanding the foregoing, an election may be filed within 30 days after a
Director first becomes an Outside Director; provided, however, the amount of compensation deferred
pursuant to such election will not exceed the portion of the Outside Director’s compensation earned
after the date the election is made. A Deferral Election may not be revoked or modified with
respect to compensation payable for any Plan Year for which it is effective. Unless either the
Deferral Election is terminated or modified as described below or the Director Separates from
Service, the Deferral Election will apply to compensation payable under Section 5.1 with respect to
each subsequent Plan Year. An Outside Director may terminate or modify his or her current Deferral
Election by filing a new Deferral Election before the first day of the Plan Year to which such
termination or modification applies.

     6.2 Interest. All amounts deferred pursuant to Section 6.1 will be credited to the Outside
Director’s applicable Plan Year Account as of the date the compensation would otherwise have been
payable, notwithstanding the Deferral Election. The amounts credited to the Plan Year Account will
be credited with interest, compounded monthly, from the date the compensation would otherwise have
been payable under Section 5.1 until the amount credited to the Account is paid to the Outside
Director. The rate of interest credited under the previous sentence will be the prime rate of
interest as reported by the Midwest edition of the Wall Street Journal for the second business day
of each quarter on an annual basis.

     6.3 Distributions. The value of an Outside Director’s Plan Year Accounts will be distributed,
or will begin to be distributed, to him or her or, in the event of his or her death, to his or her
Beneficiary, within 10 days following the earliest of:

	 	(a)	 	the date specified by the Outside Director in his or her Deferral Election for
each such Plan Year Account;
	 
	 	(b)	 	the Outside Director’s Termination Date; and

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	 	(c)	 	the date on which a Change in Control occurs.

     Each Plan Year Account will be paid to the Outside Director in a lump sum or in installments
in accordance with his or her Deferral Election for such Plan Year Account. If an Outside Director
fails to elect a payout form (and has not elected a payout form for any prior Plan Year that, in
accordance with Section 6.1, would be deemed to remain in effect until changed), his or her Plan
Year Accounts will be paid in a single lump sum.

     If an Outside Director elects to receive payment of a Plan Year Account in installments, the
payment period for the installments will not exceed ten years. The amount of each installment
payment will equal the product of (a) the balance in the Outside Director’s Plan Year Account on
the date the payment is made multiplied by (b) a fraction, the numerator of which is one and the
denominator of which is the number of unpaid remaining installments. The balance of the Plan Year
Account will be appropriately reduced to reflect any Installment Payments already made hereunder.
Notwithstanding the foregoing, in the event of a Change in Control, the balance remaining in an
Outside Director’s Account will be paid in a single lump sum payment within 10 days following the
Change in Control.

     If an Outside Director dies before he or she has received payment of all amounts due
hereunder, the balances remaining in the Outside Director’s Account will be distributed to his or
her Beneficiary in a single lump sum payment within 90 days following the Outside Director’s death.

     Notwithstanding anything to the contrary in this Section 6.3, if the Compensation Committee
determines that the Outside Director is a “specified employee” (within the meaning of Code Section
409A(a)(2)(B)), then notwithstanding any provision in the Plan to the contrary, payments triggered
by the Outside Director’s Termination Date will not be paid until six months after the Outside
Director’s Termination Date or until the Outside Director’s earlier death. The foregoing six-month
delay provision will not affect the timing of payments that would otherwise be paid more than six
months after the Outside Director’s Termination Date.

     6.4 Stock Grant Deferral. The Board may establish rules and procedures to permit Outside
Directors to defer unrestricted stock grants made pursuant to Section 5.2, as it deems appropriate
and in compliance with Code Section 409A.

     6.5 Beneficiary. An Outside Director may designate any person to whom payments are to be made
if the Outside Director dies before receiving payment of all amounts due hereunder. A Beneficiary
Designation form becomes effective only after the signed form is filed with the Secretary of the
Company while the Outside Director is alive, and will cancel any prior Beneficiary Designation
form. If the Outside Director fails to designate a Beneficiary or if all designated Beneficiaries
predecease the Outside Director, the Outside Director’s Beneficiary will be his or her estate.

8

 

Article 7. Restricted Grants

     7.1 Award Agreement. Each Outside Director who was a participant in the Plan as of January
29, 2010, will be deemed to have received a Restricted Grant with a total value equal to $72,000 on
that date. The Restricted Grant will be evidenced by an award agreement approved by the Board of
Directors that specifies the vesting period and such other provisions as the Board determines. No
Restricted Grants will be made after January 29, 2010.

     7.2 Payment of Awards. The cash value of the Restricted Grant will be paid to the Outside
Director according to the schedule set forth in the award agreement; provided, however, that an
Outside Director may defer the receipt of such cash payment via a Deferral Election, pursuant to
such procedures as may be set forth in an award agreement or as otherwise set forth by the Board of
Directors in compliance with the requirements of Code Section 409A.

Article 8. Effective Date; Grandfathered Accounts.

     8.1 Effective Date. This amended and restated Plan is effective as of January 1, 2010 (the
“Effective Date”) with respect to Nongrandfathered Accounts and will remain in effect as
provided in Section 1.3 hereof.

     8.2 Grandfathered Accounts. An Outside Director’s Grandfathered Accounts will remain subject
to the terms and conditions of the Plan as in effect on December 31, 2004.

Article 9. Miscellaneous

     9.1 Modification and Termination. The Board may at any time and from time to time, alter,
amend, modify or terminate the Plan in whole or in part.

     9.2 Indemnification. Each person who is or has been a member of the Board will be indemnified
and held harmless by the Company against and from any loss, cost, liability, or expense that may be
imposed upon or reasonably incurred by that person in connection with or resulting from any claim,
action, suit, or proceeding to which that person may be a party or in which that person may be
involved by reason of any action taken or failure to act under the Plan and against and from any
and all amounts paid by that person in a settlement approved by the Company, or paid by that person
in satisfaction of any judgment in any such action, suit, or proceeding against that person,
provided he or she gives the Company an opportunity, at its own expense, to handle and defend the
action, suit or proceeding before that person undertakes to handle and defend it. The foregoing
right of indemnification will not be exclusive of any other rights of indemnification to which an
individual may be entitled under the Company’s Certificate of Incorporation or By-Laws, as a matter
of law, or otherwise, or any power that the Company may have to indemnify him or her or hold him or
her harmless.

     9.3 Successors. All obligations of the Company under the Plan with respect to a given Plan
Year will be binding on any successor to the Company, whether the existence of the successor is the
result of a direct or indirect purchase of all or substantially all of the business and/or assets
of the Company, or a merger, consolidation, or otherwise.

9

 

     9.4 Reservation of Rights. Nothing in this Plan or in any award agreement granted hereunder
will be construed to limit in any way the Board’s right to remove an Outside Director from the
Board of Directors.

Article 10. Legal Construction

     10.1 Gender and Number. Except where otherwise indicated by the context, any masculine term
used herein will also include the feminine; the plural will include the singular and the singular
will include the plural.

     10.2 Severability. If any provision of the Plan is held illegal or invalid for any reason,
the illegality or invalidity will not affect the remaining parts of the Plan, and the Plan will be
construed and enforced as if the illegal or invalid provision had not been included.

     10.3 Requirements of Law. The issuance of payments under the Plan will be subject to all
applicable laws, rules, and regulations, and to any approvals required by any governmental agencies
or national securities exchanges.

     10.4 Securities Law and Tax Law Compliance.

	 	(a)	 	Insider Trading. To the extent any provision of the Plan or action by the
Board would subject any Outside Director to liability under Section 16(b) of the
Exchange Act, it will be deemed null and void, to the extent permitted by law and
deemed advisable by the Board.
	 
	 	(b)	 	Section 409A. This Plan is intended to comply with Code Section 409A and the
regulations thereunder, and will be administered and interpreted in accordance with
such intent. If the Company determines that any provision of the Plan is or might be
inconsistent with the requirements of Code Section 409A, it will attempt in good faith
to make such changes to the Plan as may be necessary or appropriate to avoiding an
Outside Director’s becoming subject to adverse tax consequences under Code Section
409A. No provision of the Plan will be interpreted to transfer any liability for a
failure to comply with Code Section 409A from an Outside Director or any other
individual to the Company.

     10.5 Unfunded Status of the Plan. The Plan is intended to constitute an “unfunded” plan.
With respect to any payments not yet made to an Outside Director by the Company, nothing contained
herein will give any rights to an Outside Director that are greater than those of a general
creditor of the Company.

     10.6 Governing Law. The Plan will be construed in accordance with and governed by the laws of
the State of Michigan, determined without regard to its conflict of law rules.

     10.7 Nontransferability. An Outside Director’s Account and any Restricted Units granted
hereunder may not be sold, transferred, pledged, assigned, or otherwise alienated or

10

 

hypothecated, other than by will or by the laws of descent and distribution, or pursuant to a
domestic relations order (as defined in Code section 414(p)). All rights with respect to Accounts
and Restricted Units will be available during the Outside Director’s lifetime only to the Outside
Director or the Outside Director’s guardian or legal representative. The Board of Directors may,
in its discretion, require an Outside Director’s guardian or legal representative to supply it with
evidence the Board of Directors deems necessary to establish the authority of the guardian or legal
representative to act on behalf of the Outside Director.

* * * * *

11

 

Annex A

LEAR CORPORATION

OUTSIDE DIRECTORS COMPENSATION PLAN

RESTRICTED GRANT AWARD AGREEMENT

Name:                                                                           
                      
                      
                      
                    
                    

Amount of Restricted Grant: $72,000

RESTRICTED GRANT TERMS AND CONDITIONS

          1. Definitions. Any term capitalized herein but not defined will have the meaning set
forth in the Lear Corporation Outside Directors Compensation Plan (the “Plan”).

          2. Grant, Vesting and Payment of Restricted Grant.

          (a) As of January 29, 2010 (the “Grant Date”) the Outside Director was credited with a
Restricted Grant pursuant to Section 5.3 of the Plan in the amount set forth above (an
“Award”). This Award represents a credit of a notional amount to the Outside Director’s
Account, which thereafter will be credited with interest, compounded monthly, at the prime rate of
interest as reported by the Midwest edition of the Wall Street Journal for the second business day
of each quarter on an annual basis. This grant is contingent upon the Outside Director being a
member of the Board on the Grant Date.

          (b) The Award will vest monthly over a period of thirty-six months, beginning as of the
Effective Date. If the Outside Director has a Separation from Service before the Restricted Grant
fully vests, his or her right to receive a payment with respect to the unvested portion of the
Restricted Grant will be forfeited. Notwithstanding the foregoing, (i) if prior to the date that
the Award has fully vested, the Outside Director ceases to be a Director by reason of death,
Disability or Retirement, then the portion of the Award which had not previously vested will vest
on the Termination Date and (ii) upon a Change in Control prior to or concurrent with the
Termination Date, the unvested portion of the Award will vest.

          (c) The Outside Director will be entitled to receive a cash distribution of one-third of the
Restricted Grant (plus interest accrued on that portion), to the extent then vested, on each of the
first three anniversaries of the Grant Date or at the later date elected by the Outside Director
under Section 3. Notwithstanding the foregoing, if any portion of the Award vests early due to the
death, Disability or Retirement of the Outside Director or due to a Change in Control, the entire
unpaid portion of the Award (plus interest accrued on that portion) will be paid within 10 days
after the Outside Director’s Termination Date or the Change in Control, as applicable.

1

 

          3. Election to Defer.

          (a) Subject to the requirements of this Section 3 and of Section 409A of the Code, any
Deferral Election made by the Outside Director that became irrevocable prior to January 1, 2010,
will be applicable to defer payment of any or all of his or her Restricted Grant.

          (b) In addition to the foregoing, the Outside Director may, in compliance with Section 409A of
the Code, irrevocably elect to defer payment of any or all of his or her Restricted Grant for a
period of at least five years after it otherwise would have been paid, subject to earlier payment
if the Outside Director ceases to be a Director or a Change in Control occurs. Any election made
pursuant to this Section 3(b) will be made by filing with the Secretary of the Company a written
notice to that effect on the Restricted Grant Payment Re-Deferral Election form provided by the
Company not less than 12 months before the scheduled payment date.

          (c) Any amounts deferred pursuant to this Section 3 will be treated in the same manner, and
subject to the same rules, as set forth in Article 6 of the Plan for compensation payable under
Section 5.1 of the Plan.

          5. Assignment and Transfers. The Outside Director may not assign, encumber or
transfer any of his or her rights and interests under the Award described in this document, except,
in the event of his or her death, by will or the laws of descent and distribution.

          6. Withholding Tax. The Company and any Affiliate will have the right to retain
amounts that are payable to the Outside Director hereunder to the extent necessary to satisfy any
withholding taxes, whether federal or state, triggered by the granting or vesting of an Award
reflected in this document or by the payment of cash.

          7. No Limitation on Rights of the Company. The grant of the Award described in this
document will not in any way affect the right or power of the Company to make adjustments,
reclassification or changes in its capital or business structure, or to merge, consolidate,
dissolve, liquidate, sell or transfer all or any part of its business or assets.

          8. Notice. Any notice or other communication required or permitted hereunder must be
in writing and must be delivered personally, or sent by certified, registered or express mail,
postage prepaid. Any such notice will be deemed given when so delivered personally or, if mailed,
three days after the date of deposit in the United States mail, in the case of the Company to 21557
Telegraph Road, P. O. Box 5008, Southfield, Michigan, 48086-5008, Attention: General Counsel and,
in the case of the Outside Director, to the last known address of the Outside Director in the
Company’s records.

          9. Governing Law. This document and the Award will be construed and enforced in
accordance with, and governed by, the laws of the State of Michigan, determined without regard to
its conflict of law rules.

2

 

          10. Plan Document Controls. The rights granted under this Restricted Grant document
are in all respects subject to the provisions of the Plan to the same extent and with the same
effect as if they were set forth fully therein. If the terms of this document or the Award
conflict with the terms of the Plan document, the Plan document will control.

3

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