B08 W9123822R0006 Attachment 13 Appendix K_Hill AFB-Rpair Boilers-Final Feasability Report.pdf

REPAIR BOILERS AT HEAT PLANTS,

BUILDINGS 260 AND 1286

KRSMS 170026 AND 170028

FINAL FEASIBILITY REPORT

Hill AFB, Utah

Contract No.: FA8903-16-D-0013 Task Order No.: FA8903-18-F-0163

KAL Project No. 16AFC220.11

September 16, 2019

FINAL FEASIBILITY REPORT

Repair Boilers at Heat Plants

Buildings 260 (KRSM 170026) and 1286 (KRSM 170028)

Hill Air Force Base, Utah

Contract No.: FA8903-16-D-0013

Task Order No.: FA8201-18-F-0163

KAL Project No.: 16AFC220.11

16 September 2019

Prepared for:

Hill Air Force Base

75 CEG

Environmental Management Division Civil Engineer Group

Prepared by:

KAL Architects Inc.

12 Muachly Irvine, California 92618

AECOM Technical Services, Inc.

1360 Peachtree Street NE, Suite 500 Atlanta, Georgia 30309

This page intentionally left blank.

Repair Boilers at Steam Plants, B260 and B1286 at Hill AFB, UT Contract No.: FA8903-16-D-0013 KAL Architects, Inc. Task Order No.: FA8201-18-F-0163

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TABLE OF CONTENTS

DOCUMENT CLARIFICATIONS

1 INTRODUCTION

1.1 Project Overview

1.1.1 Project Requirements

1.1.2 Compliance Standards

1.2 Life-Cycle Cost Analysis

1.3 Other Considerations

1.4 Existing Conditions

1.4.1 Hill AFB and Planned Expansion

1.4.2 Facility Infrastructure Background

1.4.3 Final Environmental Assessment

2 CONCEPTUAL SITE ANALYSIS

2.1 Building Site Conceptual Design Options

2.2 Building Siting – Utility Considerations

2.3 Potential Siting Locations

2.3.1 B260 Site A

2.3.2 B260 Site B

2.3.3 B1286 Site A

3 OPTIONS ANALYSIS

3.1 Life Cycle Cost Analysis (LCCA)

3.1.1 Option #1

3.1.2 Option #2

3.1.3 Option #3

3.1.4 LLC and Annual Cost Savings

3.2 Conceptual Design Options

3.3 Option #1: Replace Boilers in B260 and B1286 – No CHP

3.3.1 Description

3.3.2 Anticipated Construction Cost

3.3.3 Anticipated Construction Schedule

3.4 Option #2: New B260 with CHP and B1286 Boiler Upgrade

3.4.1 Description

3.4.2 Anticipated Construction Cost

3.4.3 Anticipated Construction Schedule

Page ii

3.5 Option #3: Decentralization of Southwest Steam Loop

3.5.1 Description

3.5.2 Anticipated Construction Cost

3.5.3 Anticipated Construction Schedule

3.6 Architectural Conceptual Design Options

3.7 Electrical Conceptual Design Options

3.7.1 Option #1: Replace Boilers in B260 and B1286, No CHP

3.7.2 Option #2: New B2XX with CHP and B1286 Boiler Upgrade

3.7.3 Option #3: Decentralization of Southwest Steam Loop

3.8 Generator Sets Options Review

3.8.1 Basis of Design

3.8.2 Solar Turbines

4 OPTION #1 EVALUATION

4.1 Utilities

4.1.1 Natural Gas

4.1.2 Water

4.1.3 Sanitary Sewerage

4.1.4 Steam Distribution Facilities

4.1.5 Electrical

4.1.6 Load Study/Verification

4.2 Physical Security

4.2.1 Security Design Criteria

4.2.2 Objective

4.2.3 Design Approach

4.3 Energy and Sustainability

4.3.1 Energy Code Design Criteria

4.3.2 Metering

4.3.3 Sustainability

4.4 Architectural

4.4.1 Architectural Design Criteria

4.4.2 Architectural Scope of Work

4.4.3 Option #1: Replace Existing Boilers within Existing Buildings

4.5 Civil/Site

4.5.1 Surrounding Land Uses

4.5.2 Airfield Runway Clearance

4.5.3 Wetlands

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4.5.4 Topography

4.5.5 Biological and Other Environmental Considerations

4.5.6 Historically Significant Items

4.5.7 Flood Hazards

4.5.8 Underground Utilities

4.5.9 Other On-Site Underground Improvements near the Project Area: USTs

4.5.10 Existing Soil Conditions

4.6 Mechanical

4.6.1 Mechanical Design Criteria

4.6.2 Survey of Existing Systems – Steam

4.6.3 Mechanical Concepts: Option #1

4.6.4 Option #1 Calculations

4.7 Electrical

4.7.1 Electrical Design Criteria

4.7.2 Survey of Existing Electrical Systems (Findings Report)

4.7.3 Electrical Load Calculations

4.7.4 Utility Company Correspondence

4.8 Structural

4.8.1 Structural Design Criteria

4.8.2 Seismic

4.8.3 Existing Buildings

4.8.4 New Work Option #1

4.8.5 Structural Option #1

4.9 Environmental Considerations

4.9.1 Underground Storage Tanks (USTs)

4.9.2 Pre-Demolition / Hazardous Materials

4.10 Permitting and Regulatory Considerations

4.10.1 Floodplain

4.10.2 Regulatory Standards

4.10.3 Background

4.10.4 Environmental Options

4.11 Program Schedule and Cost

4.11.1 Program Schedule

4.11.2 Conditions That Will Influence Project Schedule

4.11.3 Approximate Program Construction Cost Estimates

5 OPTION #2 EVALUATION

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5.1 Utilities

5.1.1 Natural Gas

5.1.2 Water

5.1.3 Sanitary Sewerage

5.1.4 Steam Distribution Facilities

5.1.5 Electrical

5.1.6 Load Study/Verification

5.2 Physical Security

5.2.1 Security Design Criteria

5.2.2 Objective

5.2.3 Design Approach

5.3 Energy and Sustainability

5.3.1 Energy Code Design Criteria

5.3.2 Metering

5.3.3 Sustainability

5.4 Architectural

5.4.1 Architectural Design Criteria

5.4.2 Architectural Scope of Work

5.4.3 Option #2: New B260 (“B2XX”)

5.5 Civil/Site

5.5.1 Surrounding Land Uses

5.5.2 Airfield Runway Clearance

5.5.3 Wetlands

5.5.4 Topography

5.5.5 Biological and Other Environmental Considerations

5.5.6 Historically Significant Items

5.5.7 Flood Hazards

5.5.8 Underground Utilities

5.5.9 Other On-Site Underground Improvements near the Project Area: USTs

5.5.10 Existing Soil Conditions

5.6 Mechanical

5.6.1 Mechanical Design Criteria

5.6.2 Survey of Existing Systems – Steam

5.6.3 Mechanical Concepts: Option #2

5.6.4 Option #2 Calculations

5.7 Electrical

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5.7.1 Electrical Design Criteria

5.7.2 Survey of Existing Electrical Systems (Findings Report)

5.7.3 Electrical Load Calculations

5.7.4 Utility Company Correspondence

5.8 Structural

5.8.1 Structural Design Criteria

5.8.2 Seismic

5.8.3 Structural Option #2

5.9 Environmental Considerations

5.9.1 Underground Storage Tanks (USTs)

5.9.2 Pre-Demolition / Hazardous Materials

5.10 Permitting and Regulatory Considerations

5.10.1 Floodplain

5.10.2 Regulatory Standards

5.10.3 Background

5.10.4 Environmental Options

5.11 Program Schedule and Cost

5.11.1 Program Schedule

5.11.2 Conditions That Will Influence Project Schedule

5.11.3 Approximate Program Construction Cost Estimates

6 OPTION #3 EVALUATION

6.1 Utilities

6.1.1 Natural Gas

6.1.2 Water

6.1.3 Sanitary Sewerage

6.1.4 Steam Distribution Facilities

6.1.5 Electrical

6.1.6 Load Study/Verification

6.2 Physical Security

6.2.1 Security Design Criteria

6.2.2 Objective

6.2.3 Design Approach

6.3 Energy and Sustainability

6.3.1 Energy Code Design Criteria

6.3.2 Metering

6.3.3 Sustainability

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6.4 Architectural

6.4.1 Architectural Design Criteria

6.4.2 Architectural Scope of Work

6.4.3 Option #3

6.5 Civil/Site

6.5.1 Surrounding Land Uses

6.5.2 Airfield Runway Clearance

6.5.3 Wetlands

6.5.4 Topography

6.5.5 Biological and Other Environmental Considerations

6.5.6 Historically Significant Items

6.5.7 Flood Hazards

6.5.8 Underground Utilities

6.5.9 Other On-Site Underground Improvements near the Project Area: USTs

6.5.10 Existing Soil Conditions

6.6 Mechanical

6.6.1 Mechanical Design Criteria

6.6.2 Survey of Existing Systems – Steam

6.6.3 Mechanical Concepts Option #3

6.6.4 Option #3 Calculations

6.7 Electrical

6.7.1 Electrical Design Criteria

6.7.2 Survey of Existing Electrical Systems (Findings Report)

6.7.3 Electrical Load Calculations

6.7.4 Option #3 Decentralization of Southwest Steam Line Electrical Work

6.7.5 Utility Company Correspondence

6.8 Structural

6.8.1 Structural Design Criteria

6.8.2 Seismic

6.8.3 Existing Buildings

6.8.4 Structural Option #3

6.9 Environmental Considerations

6.9.1 Underground Storage Tanks (USTs)

6.9.2 Pre-Demolition/Construction

6.10 Permitting and Regulatory Considerations

6.10.1 Floodplain

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6.10.2 Regulatory Standards

6.10.3 Background

6.10.4 Environmental Options

6.11 Program Schedule and Cost

6.11.1 Program Schedule

6.11.2 Conditions That Will Influence Project Schedule

6.11.3 Program Approximate Construction Cost Estimates

7 REFERENCES

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LIST OF FIGURES

Figure 1-1: Hill AFB, UT

Figure 1-2: Building 260 Southwest Steam Line

Figure 1-3: B260 Underground Storage Tank Locations

Figure 1-4: – Building 1286 Underground Storage Tank Locations

Figure 2-1: Proposed New CHP Site – Option 2

Figure 2-2: Site Analysis Diagram Indicating Utilities

Figure 2-3: B260 Site A –Existing Building Site

Figure 2-4: B260 Site B – New Area by Airfield

Figure 2-5: B1286 Site A – Existing Building Site

Figure 3-1: Option #1 – Replace Boilers in Existing B260

Figure 3-2: Option #1 – Replace Boilers at Existing B1286

Figure 3-3: Option #2 – New B2XX with CHP

Figure 3-4: Option #3 – New Pool Building addition

Figure 3-5: Proposed CHP Building

Figure 3-6: Proposed CHP Building – Elevations

Figure 3-7: Option #1 – One Line Diagram of B260 Existing Demolition

Figure 3-8: Option #1 –B260 New One Line Diagram

Figure 3-9: Option #1 –B1286 Existing Demolition One Line Diagram

Figure 3-10: Option #1 –B1286 New One Line Diagram

Figure 3-11: Option #2 Single Line Diagram

Figure 4-1: B260 – Estimated Hourly Steam Demand (Pre-ESPC Project)

Figure 4-2: B260 – Estimated Hourly Steam Demand (Post-ESPC project)

Figure 4-3: B1286 – Estimated Hourly Steam Demand

Figure 4-4: Existing Substation Locations

Figure 5-1: B260 – Estimated Hourly Steam Demand (Pre-ESPC Project)

Figure 5-2: B260 – Estimated Hourly Steam Demand (Post ESPC project)

Figure 5-3: B1286 – Estimated Hourly Steam Demand

Figure 5-4: Existing Substation Locations

Figure 6-1: B260 – Estimated Hourly Steam Demand (Pre-ESPC Project)

Figure 6-2: B260 – Estimated Hourly Steam Demand (Post ESPC project)

Figure 6-3: B1286 – Estimated Hourly Steam Demand

Figure 6-4: Aerial View of Buildings Located within Southwest Steam Line (Option #3)

Figure 6-5: Typical SW Steam Loop Housing Mechanical Room

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Figure 6-6: Existing Substation Locations

Page x

LIST OF TABLES

Table 1-1: Existing Boilers

Table 2-1: Site Options Summary

Table 3-1: Option #1 LCCA

Table 3-2: Option #2 LCCA

Table 3-3: Option #3 LCCA

Table 3-4: Options Summary

Table 4-1: Maximum and Minimum Electrical Load Data for 46 kV Distribution System

Table 4-2: Estimated Electrical Load Data per Substation

Table 4-3: Estimated Load Distribution per Substation

Table 4-4: Preliminary Building Code Analysis

Table 4-5: B260 – Existing Boilers

Table 4-6: B260 – Existing Steam Production (Pre-ESPC Project)

Table 4-7: B260 – Existing Steam Production (Post ESPC Project)

Table 4-8: B1286 – Existing Boilers

Table 4-9: B1286 – Existing Steam Production

Table 4-10: Option #1 B260 – Post ESPC Utility Energy Savings

Table 4-11: Option #1 B1286 – Utility Energy Savings

Table 4-12: Option #1 Boiler Plant Utility Energy Savings

Table 4-13: Option #1 Boiler Plant Monetary Savings

Table 4-14: Option #1 Estimated B260 Load Calculation

Table 4-15: Option #1 Estimated B1286 Load Calculation

Table 4-16: Option #1 Estimated Utility Transformer Load Calculation

Table 4-18: Proximate Construction Cost Estimate – Option #1

Table 5-1: Maximum and Minimum Electrical Load Data for 46 kV Distribution System

Table 5-2: Estimated Electrical Load Data per Substation

Table 5-3: Estimated Load Distribution per Substation

Table 5-4: Preliminary Building Code Analysis

Table 5-5: B260 – Existing Boilers

Table 5-6: B260 – Existing Steam Production (Pre-ESPC Project)

Table 5-7: B260 – Existing Steam Production (Post ESPC Project)

Table 5-8: B1286 – Existing Boilers

Table 5-9: B1286 – Existing Steam Production

Table 5-10: Option #2 B260 – Post ESPC Utility Energy Savings

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Table 5-11: Option #2 B2XX – CHP Steam Production Post-ESPC

Table 5-12: Option #2 Boiler Plant Utility Energy Savings

Table 5-13: Option #2 Boiler Plant Monetary Savings

Table 5-14: Option #2 Estimated B1286 Load Calculation

Table 5-15: Option #2 Estimated Utility Transformer Load Calculation

Table 5-16: Estimated B2XX CHP Building Load Analysis

Table 5-17: Option #2 Estimated Circuit Loading for Site Distribution Tie-In Points

Table 5-20: Proximate Construction Cost Estimate – Option #2

Table 6-1: Maximum and Minimum Electrical Load Data for 46 kV Distribution System

Table 6-2: Estimated Electrical Load Data per Substation

Table 6-3: Estimated Load Distribution per Substation

Table 6-4: Preliminary Building Code Analysis

Table 6-5: B260 – Existing Boilers

Table 6-6: B260 – Existing Steam Production (Pre-ESPC Project)

Table 6-7: B260 – Existing Steam Production (Post ESPC Project)

Table 6-8: B1286 – Existing Boilers

Table 6-9: B1286 – Existing Steam Production

Table 6-10: Option #3 – Existing SW Steam Loop Consumption Per Building

Table 6-11: Option #3 – Combined Monthly Steam Consumption Existing SW Steam Loop Buildings

Table 6-12: Southwest Steam Loop Building – Mechanical Demolition Work

Table 6-13: Southwest Steam Loop Building – Mechanical New Work

Table 6-14: Option #3 Southwest Loop Buildings – Utility Energy Savings

Table 6-15: Option #3 Boiler Plant Utility Energy Savings

Table 6-16: Option #3 Boiler Plant Monetary Savings

Table 6-17: Option #3 Estimated B260 Load Calculation

Table 6-18: Option #3 Estimated B1286 Load Calculation

Table 6-19: Option #3 Estimated Utility Transformer Load Calculation

Table 6-20: Option 3 Electrical Demolition

Table 6-21: Option 3 Electrical New Work

Table 6-22: Option #3 Boilers

Table 6-25: Approximate Construction Cost Estimate – Option #3

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Appendices

Appendix A - Option 1 Plans

Appendix B - Option 2 Plans

Appendix C - Option 3 Plans

Appendix D - Site Survey Report

Appendix E - Cost Estimate

1. Option 1

2. Option 2

3. Option 3

Appendix F - BACT Analysis Supporting Documentation

Appendix G - Calculations and Cut-Sheets

1. Option 1 Calculations

2. Option 2 Calculations

3. Option 3 Calculations

4. HAFB Equipment Cut Sheets

Appendix H- LCCA calculations.

Page xiii

Acronyms and Abbreviations

ABA Architectural Barriers Act

ABAAS Architectural Barriers Act Accessibility Standards

ABW Air Base Wing

ACI American Concrete Institute

A-E, AE Architecture Engineering consultant

AFB Air Force Base

AFMC Air Force Material Command

AFCEC/CO Air Force Civil Engineering Center / Operations Directorate

AFSC Air Force Sustainment Center

AHU Air Handling Unit

AISC American Institute of Steel Construction

ALC Air Logistics Command

AM Ante meridiem; morning

AMRS Automatic Meter Reading System

ANSI American National Standards Institute

API American Petroleum Institute

ASCE American Society of Civil Engineers

ASHRAE American Society of Heating, Refrigerating and Air-Conditioning Engineers

AST Aboveground Storage Tank

ATC Applied Technology Council

AT/FP Antiterrorism/force protection

ATS Automatic Transfer Switch

B260 Building 260

B1286 Building 1286

B2XX New building, part of Option #2

BACT Best Available Control Technology

BLCC Building Life Cycle Cost Program

BHP Brake Horsepower

Btu British Thermal Unit

CAA Clean Air Act

CCTV Closed Circuit Television Monitoring and Surveillance

CFR Code of Federal Regulations

Page xiv

CHP Combined Heat and Power

CO Carbon monoxide

DoD Department of Defense

DOE Department of Energy

DOT Department of Transportation

DSPI Duress, Security Phones, and Intercom System dth Dekatherm

EPA Environmental Protection Agency

ESPC Energy savings performance contract

FEMA Federal Emergency Management Agency

FGR Flue gas recirculation

FIRM Flood Insurance Rate Map

HMA Hot-mix asphalt

HRSG Heat Recovery Steam Generator

HVAC Heating, Ventilation, and Air Conditioning

IBC International Building Code

IDS Intrusion Detection System

IEBC International Existing Buildings Code

IEEE Institute of Electrical and Electronics Engineers

IFC International Fire Code

IMC International Mechanical Code

IPC International Plumbing Code

KAL Architects, Inc.

Kcmil Thousands of circular mils

KRSM Four Digit Identifier for Hill AFB kV Kilovolts kVA Kilovolt-Ampere kVAR Kilovolt-ampere-reactive kW Kilowatt lbs/hr Pounds per hour

LCCA Life Cycle Cost Analysis

LOP Level of Protection

MCC Motor Control Center

MDP Main Distribution Panel

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MIN Minimum

MW Megawatt

MBH One Thousand British Thermal Units per hour

MMBH One Million British Thermal Units per hour

MMBtu One Million British Thermal Units

NAAQS National Ambient Air Quality Standard

NEC National Electrical Code

NEMA National Electrical Manufacturers Association

NESHAP National Emissions Standards for Hazardous Air Pollutants

NFPA National Fire Protection Association

NIST National Institute of Standards and Technology

NOx Oxides of nitrogen

OSHA Occupational Health and Safety Administration

OSHPD California Office of Statewide Health Planning and Development

PACS Physical Access Control System pf Power factor

PLC Programmable Logic Control

PM Post meridian; evening

PM2.5 Particulate Matter Smaller Than 2.5 Microns ppm Parts Per Million psig Pounds per square inch, gage

QRP Qualified Recycling Program

SCR Selective Catalytic Reduction

SEAOC Structural Engineers Association of California

SIP State Implementation Plan

SOP Standard Operating Procedure

SO2 Sulfur Dioxide

sq. ft. Square Feet

SW Southwest

UFC Unified Facilities Criteria

UFGS Unified Facilities Guide Specifications

UL Underwriters Laboratory

UST Underground Storage Tank

V Volt

Page xvi

XRF X-Ray Fluorescence

DOCUMENT CLARIFICATIONS

Objective

The objective of this Final Feasibility Study Report is to memorialize the concepts, design elements, assumptions, clarifications, decisions made to date, etc., for the proposed “Repair and or replacement of Boilers at Steam Plants, B260 and B1286 Feasibility Study for Hill Air Force Base (AFB) in Hill AFB, Utah.”

Capturing and communicating the design criteria and design intent in such a narrative form is vital in verifying that KAL/AECOM is complying with known requirements.

Scope

This Final Feasibility Study Report is one of the Basis of Design Deliverables prepared under this contract and is made part of the design phase submittal for the “Repair Boilers at Steam Plants, B260 and B1286 Project.”

Limitations

This Final Feasibility Study Report has been prepared to memorialize the design decisions as the basis for the construction documents. Please be advised that the basis of design document will be updated upon receipt of review comments. Multiple documents prepared by KAL/AECOM may have been noted herein and are incorporated by reference making them part of this document.

Document Revision History

This document is a Final Feasibility Study Report as prepared under study phase submittal of the proposed “Repair Boilers at Steam Plants, B260 and B1286 project.” The “Basis of Design” document is subject to updating based upon receipt of review comments.

EXECUTIVE SUMMARY

The Architecture Engineering consultant (A-E) has been tasked to develop a life cycle cost analysis (LCCA) for the replacement of 11 boilers, using best available control technology (BACT), to address serious nonattainment under the Clean Air Act (CAA). The boiler replacements will use one or a combination of the design options described below.

Option #1

Option #1 will include the replacement of eight existing boilers in Building 260 (B260) and three at B1286 with new dual-fuel (natural gas/fuel oil) boilers that meet BACT. This option will require phasing the boiler replacement in the existing plants to maintain steam production for the existing load. The existing buildings will require new wall openings and an emergency boiler to maintain “N+1” boiler redundancy in the plants.

The boilers in B260 will be replaced with five new 50 million Btu/hour (MMBH) boilers and those in B1286 with two new 50 MMBH boilers. The boilers will achieve ultra-low oxides of nitrogen (NOx) emissions of 9 parts per million (ppm). The existing boiler fuel oil underground storage tanks (USTs) in both buildings will be removed and replaced with aboveground storage tanks (AST), which are sized for seven days of storage during peak heating season. The existing buildings will have seismic retrofitting and supporting equipment (deaerator, pumps, etc.)

upgraded. The undersized emergency generator at B1286 will be replaced to accommodate larger blower motor sizes due to flue gas recirculation (FGR).

A full utility survey has been conducted to provide existing utility locations. The survey includes the locations of the USTs for fuel-oil storage. Utility lines requiring repair, replacement, or relocation have been included in the cost estimate. This option will cost $46.3 million and has a savings-to-investment ratio (SIR) of 0.26.

Option #2

Option #2 will include the replacement of eight existing boilers in B260 with a combination of one new combined heat and power (CHP) plant with steam generation and conventional dual-fuel boilers of enough quantity and size to meet demand. At B1286, this option will include the replacement of three existing boilers in with conventional type boilers of enough quantity and size to meet demand. This option will include a new building, referred to as “B2XX,” with three 95 MMBH boilers that will achieve ultra-low NOx emissions of 9 ppm and one 4.5-megawatt (MW) dual-fuel turbine CHP with a Heat Recovery Steam Generator (HRSG) sized at 29.2 MMBH unfired, and 62.5 MMBH with duct firing.

The CHP will achieve ultra-low NOx emissions of 9 ppm. The new site will include redundant

12.47 kilovolt (kV) utility tie-in points for increased resiliency. A new 1.75 MW diesel emergency generator will provide backup power to the boiler plant, including the black start of the CHP. The existing USTs will be removed and replaced with AST options which are sized for seven days of storage during peak heating season for each building. The existing boilers in B1286 will be replaced with two new 50 MMBtu boilers (this is the same as Option #1). This option will cost $90.4 million and has a SIR of 0.26.

Option #3

Option #3 will decentralize the southwest steam line and convert the buildings connected to B260 to natural gas heating. Option #3 will provide an SIR that is estimated to be greater than

1.0 and provide a parametric cost estimate of converting each facility to natural gas heating.

The existing steam to hot water converters will be demolished and replaced with hot water boilers and water heaters, depending on the building. Buildings that require steam, such as the dining hall kitchen, will have small package steam boilers added. These buildings account for approximately 3% of the steam demand in B260 and have low SIRs. This option will replace the steam plants and the USTs at B260 and B1286 with ASTs, as in Option #1. The existing boilers at B260 will be replaced with five 50 MMBH units, and at B1286 with two 50 MMBH. The existing emergency generator will be replaced in B1286. This option costs $50.5 million and has a savings to investment ratio of 0.25.

1 INTRODUCTION

Hill Air Force Base (AFB) is located in Ogden, Utah, and is part of Air Force Materiel Command (AFMC). Hill AFB is one of three sustainment complexes, which are part of the Air Force Sustainment Center (AFSC) headquartered at Tinker AFB, Oklahoma. Hill AFB is home to multiple missions under multiple commands all working together to support America’s defense.

The mission of AFSC is to sustain weapon-system readiness to generate air power for America.

The Air Logistics Command (ALC) manages depot-level maintenance production and manufacturing facilities and laboratories in the restoration of Air Force equipment and aircraft to serviceable condition.

The host organization at Hill AFB is the 75th Air Base Wing (ABW), which is responsible for facilities and equipment support, for logistics, medical, civil engineering, security and mission support functions.

Tenants at Hill AFB include the Air Combat Command’s 388th Fighter Wing and 729th Air Control Squadron, Air Force Reserve Command’s 419th Fighter Wing, and Air Education and Training Command’s 367th Training Support Squadron and 368th Recruiting Squadron.

An aerial view of Hill AFB is shown in Figure 1-1.

Figure 1-1: Hill AFB, UT

1.1 PROJECT OVERVIEW

This task involves the repair of boilers in B260 and B1286 for Hill AFB projects KRSM 170026 and KRSM 170028, respectively, under Contract Number FA8903-16-D-0013 and Task Order Number FA8903-18-F-0167. The KAL Architects, Inc., (KAL) Team will provide A-E services to evaluate feasibility and develop an LCCA in support of:

KRSM 170026, Repair Boilers at Steam Plant B260: repair by replacement all boilers in B260; and

KRSM 170028, Repair Boilers at Steam Plant B1286: repair by replacement all boilers in B1286.

1.1.1 Project Requirements

The requirement for this project is to evaluate feasibility and develop a complete LCCA to replace 11 existing boilers for compliance with BACT requirements for serious nonattainment under the Clean Air Act. Options for the replacement include using one or any combination of three possible design alternatives. Design alternatives are:

Option #1

This option pertains to both projects, KRSM 170026 and KRSM 170028. This option includes the replacement of the existing boilers in B260 and B1286 with new boilers of enough quantity and size to meet demand as well as BACT, as outlined below:

KRSM 170026 (B260)

Demolition/Removal:

– Eight Boilers

– Six USTs

New Construction:

– Five new 50 MMBH, High Efficiency, Ultra-Low NOx Boilers

– Six new 50,000-gallon ASTs

– New wall openings

– Install two new access doors through which installation and maintenance of boilers will be performed

– Reroute steam pipes as needed

KRSM 170028 (B1286)

Demolition/Removal:

– Three Boilers

– Two USTs

New Construction:

– Two new 50 MMBH, High Efficiency, Ultra-Low NOx Boilers

– Three new 25,000-gallon ASTs

– One Emergency Stand-by Diesel Generator

– One new 450 kW Emergency Stand-By Diesel Generator

– Reroute steam pipes as needed

Option #2

This option pertains to both projects, KRSM 170026 and KRSM 170028. This option includes the replacement of the existing boilers in B260 with a combination of one new CHP plant with steam generation and conventional type boilers of enough quantity and size to meet demand as well as BACT. Replace three existing boilers in B1286 with conventional type boilers of enough quantity and size to meet demand (this is the same as Option #1 regarding project KRSM 170028). Details of this option include the following:

KRSM 170026 (B260)

Demolition/Removal:

– N/A; Existing B260 to remain

New Construction:

– Construct new building “B2XX”

– Three new 95 MMBH, High Efficiency, Ultra-Low NOx Boilers

– One 4.5 MW CHP unit

– Six new 50,000-gallon ASTs

– One new 1750 kW Emergency Stand-by Diesel Generator

– Install interconnect power line for generated electricity to be fed into the base electrical distribution system.

KRSM 170028 (B1286)

Demolition/Removal:

– Three Boilers

– Two USTs

New Construction:

– Two new 50 MMBH, High Efficiency, Ultra-Low NOx Boilers

– Three new 25,000-gallon ASTs

– One Emergency Stand-by Diesel Generator

– One new 450 kW Emergency Stand-By Diesel Generator

– Reroute steam pipes as needed

Option #3

This option pertains to both projects KRSM 170026 and KRSM 170028. This option includes the replacement of the existing boilers in B260 and B1286 with new boilers of enough quantity and size to meet demand, as well as BACT, which is similar to Option #1. This option will also include the decentralization of the facilities that are serviced by the central steam plant, B260, on the southwest steam loop. These facilities will instead be served by individual facility boilers and water heaters.

KRSM 170026 (B260)

Demolition/Removal:

– Eight Boilers

– Six USTs

– Individual southwest loop facility steam heat exchangers, hot water storage tanks, steam unit heaters, and associated steam piping depending on each facility.

New Construction:

– Five new 50 MMBH, High Efficiency, Ultra-Low NOx Boilers

– Six new 50,000-gallon ASTs

– New wall openings

– Install two new access doors through which installation and maintenance of boilers will be performed

– Reroute steam pipes as needed

– New natural gas hot water boilers, domestic water heaters, electric unit heaters and associated piping per each facility (equipment type, sizes, and quantity dependent per each southwest loop facility)

– Steam boiler package in B519

– New pool heater and pumps in B461

KRSM 170028 (B1286)

Demolition/Removal:

– Three Boilers

– Two USTs

New Construction:

– Two new 50 MMBH, High Efficiency, Ultra-Low NOx Boilers

– Three new 25,000-gallon ASTs

– One Emergency Stand-by Diesel Generator

– One new 450 kW Emergency Stand-By Diesel Generator

– Reroute steam pipes as needed

1.1.2 Compliance Standards

KAL-AECOM Team will coordinate with 75 CEG/CEIEA to verify that each approach meets all air quality permitting and notification requirements, as well as BACT as defined in 40 Code of Federal Regulations (CFR) 51.1010(a) for Serious Nonattainment Areas. Data required for a BACT analysis will be provided with the submittal of the final report. Each alternative listed above will be evaluated for compliance with the following non-inclusive list of standards:

Unified Facilities Criteria (UFC) 1-200-02 High Performance and Sustainable Building Requirements

Air Force Energy Flight Plan 2017-2036 dated 6 Jan 17

ASHRAE Standard 90.1

Energy Policy Act 2005 as codified in 10 CFR Parts 433, 434 and 435

National Emissions Standards for Hazardous Air Pollutants (NESHAP)

The Hill AFB Facility Design Standard

New Source Performance Standards (NSPS) – 40 CFR Part 60

Utah Administrative Codes R307-401

State Implementation Plan (SIP) – Subpart H

The boilers to be replaced are listed in Table-1-1.

Table 1-1: Existing Boilers

Source ID (AQUIS) Capacity (MMBH) Building No. Year Built Control Technology

3501 80 260 1975 None

3502 80 260 1975 None

3503 50 260 1956 None

3504 50 260 1956 None

3505 50 260 1959 None

3506 50 260 1956 None

3507 87.5 260 1989 Low NOx Burners

3508 87.5 260 1988 Low NOx Burners

3519 60 1286 1970 None

3520 40 1286 1965 None

3521 40 1286 1965 None

1.2 LIFE-CYCLE COST ANALYSIS

For each option listed above, an LCCA will completed in compliance with Section 6.4 of the Hill AFB Facility Design Standard, UFC 1-200-02 and 10 CFR 436 to demonstrate life-cycle cost effectiveness. The KAL Team will identify facilities currently connected to the southwest steam line (shown in Figure 1-2) that can be converted to natural gas heating with an SIR that is estimated to be greater than 1.0 and will provide a parametric cost estimate for each facility. The extent of facilities to be considered is indicated within the red perimeter on Figure 1-2.

Figure 1-2: Building 260 Southwest Steam Line

1.3 OTHER CONSIDERATIONS

Emergency stand-by diesel generators cannot be replaced by centralized generators per AFI32- 1062.

The KAL-AECOM Team will develop a parametric cost estimate to renovate existing buildings, B260 and B1286, to current applicable Unified Facilities Criteria (UFC) and Hill AFB Facility Design Standards. The cost estimate will include costs to upgrade facilities to current anti-terrorism force protection (AT/FP), fire alarm/suppression, security, and other applicable standards. The KAL Team will also develop a parametric cost to demolish existing facilities and build new to current standards.

The government will provide any as-builts for this area that may be available; however, it is assumed that these may not exist and are likely to be inaccurate due to the age of any as-builts that may be available. The Base RED STAKES office and/or 75 CEG Surveyor will assist in locating underground utilities as needed; and the Base Abatement shop will provide a report locating known asbestos, lead based paint, or other pathogens requiring abatement for this project. The areas requiring abatement will be included in the LCCA.

The KAL-AECOM Team will conduct site surveying, including a topographic survey for utility location and verification. Six USTs at B260, and two USTs at B1286 (Figures 1-3 and 1-4) will be surveyed for condition and location. The utilities survey will also locate all utilities within a thirty-foot radius of B260 and B1286. This survey will include collaboration with the GeoBASE and RED STAKES offices on base to locate utilities relevant to the design for these projects and coordination with Base shops to open manholes and survey utility inverts to determine utility line depths across the site as accurately as possible. Potholing will be conducted by drilling a core through the existing pavement and using a vacuum method for potholing through the cored hole.

The hole will be backfilled with soil, base course and minimum of three inches of hot-mix asphalt (HMA) material and compacted. The final submitted report will include a utility condition assessment and will show locations of the existing utilities and recommendations for repair or replacement. Costs for utility upgrades to support each option above will be included in the LCCA.

Figure 1-3: B260 Underground Storage Tank Locations

Figure 1-4: – Building 1286 Underground Storage Tank Locations

1.4 EXISTING CONDITIONS

1.4.1 Hill AFB and Planned Expansion

Hill AFB comprises approximately 6,700 acres and 1,400 buildings and is served by several central heating plants that provide steam for domestic water and building heat.

1.4.2 Facility Infrastructure Background

Steam plants, B260 and B1286, consist of water-tube boilers of various sizes, which deliver steam to multiple buildings for building and/or domestic water heating. The existing boilers are listed in Table 1-1, above.

1.4.3 Final Environmental Assessment

The State Implementation Plan (SIP) requires the boilers listed in Table 1-1 to be removed by December 2024. The SIP also caps NOx emissions at 95 lb/hr for units of 5 MMBH or greater.

Current combined maximum capacity of Hill AFB boilers subject to this condition is approximately 82 lb/hr NOx. Actual emissions are significantly lower.

2 CONCEPTUAL SITE ANALYSIS

2.1 BUILDING SITE CONCEPTUAL DESIGN OPTIONS

The design team analyzed the areas around B260 and B1286 for potential sites for additions to the boiler plant, if required. Figure 2-1 and Table 2-1 below illustrate potential sites examined for the CHP building.

These sites met the following criteria:

Proximity to existing boiler plants

Available footprint with ability to construct without disrupting operations

Figure 2-1: Proposed New CHP Site – Option 2

Table 2-1: Site Options Summary

Site Options Pros Cons Site Option #1

Demolish existing buildings around B260

Closest to existing electrical switchgear

Existing USTs are removed

Low cost, single level construction

Site utilities require relocation

Longer schedule due temporary facilities and utility relocation

Increased costs due to inclusion of UST removal

Site Option #2

Southeast of the existing energy plant building

Does not require removal of USTs and avoids most underground utilities

Low cost, single level construction

Building restricts truck dock maneuvering space.

Removes existing contractor laydown space.

2.2 BUILDING SITING – UTILITY CONSIDERATIONS

The areas around B260 include existing buildings, underground storage tanks, underground utilities, and roadways. A new location, which currently is being used for storage with minimal utilities, was chosen as the best option for a new “B2XX,” boiler and CHP building. At B1286, there were no viable options for a new building because of the proximity to other buildings and lack of open land area, except required parking that was not able to be relocated.

The underground storage tanks will be removed for both B260 and B1286 options. Information for these are in the Civil/Site sections of the report.

Figure 2-2 illustrates some of these restrictions and considerations. A full-size drawing can be found in the appendix of this report.

Figure 2-2: Site Analysis Diagram Indicating Utilities

2.3 POTENTIAL SITING LOCATIONS

The following locations were analyzed as possible locations for a new boiler plant or new CHP.

2.3.1 B260 Site A

Site A (Figure 2-3) is the existing energy plant at B260 and surrounding area. Neither a new boiler plant nor the addition of a CHP was feasible because of the limited area.

Figure 2-3: B260 Site A –Existing Building Site

2.3.2 B260 Site B

Site “B” (Figure 2-4) is located directly southeast of B260.

Figure 2-4: B260 Site B – New Area by Airfield

2.3.3 B1286 Site A

B1286 Site A (Figure 2-5) is within the existing energy plant. The existing plant and surrounding area were analyzed. No other options were considered because the nearby parking lot was not available for a new building.

Figure 2-5: B1286 Site A – Existing Building Site

3 OPTIONS ANALYSIS

3.1 LIFE CYCLE COST ANALYSIS (LCCA)

An LCCA was performed using the Building Life-Cycle Cost (BLCC) program created by the National Institute of Standards and Technology (NIST). Version BLCC 5.3-19 was used with the latest discount factors and DOE (Department of Energy) energy price projections. The program is set to Federal Analysis, Financed Project with a 25-year term, which is the maximum study period allowed per 10 CFR 436A for most projects. UFC-1-02 requires system alternatives to use expected useful life of components. The water-tube boilers, pumps, tanks, and heat exchangers all have an expected useful life of 25 years or greater.

The LCCA considers initial cost, annual utility consumption, and costs associated with maintenance over the life of the equipment. A total of three options were considered. All LCCA options were calculated with post ESPC project steam demand reductions. . All LCCA reports can be found in Appendix H.

The design options are described below:

3.1.1 Option #1

Option #1 will include the replacement of the existing boilers in B260 and B1286 with new boilers that meet BACT. This option will require phasing the replacement of the boilers in the existing plants to maintain steam production for the existing load. The existing buildings will require new wall openings and maintain “N+1” boiler redundancy.

The existing boilers will be replaced with five new 50 MMBH boilers at B260 and two new 50 MMBH boilers at B1286. The boilers will achieve ultra-low NOx emissions of 9 ppm (parts per million). The existing electrical system and diesel generator will be mostly reused at B260. The existing electrical system and diesel generator will be replaced for increased load at B1286. The USTs will be replaced with ASTs sized for seven days of storage during peak heating season.

This option will cost $46.3 million.

3.1.2 Option #2

Option #2 will replace eight existing boilers in B260 with a combination of one new CHP plant with steam generation, and conventional type steam boilers of sufficient capacity to meet demand. B1286 will have the three existing boilers replaced with conventional type boilers of sufficient capacity to meet demand (this is the same as Option #1). Option #2 will include a new B260 facility, “B2XX”, with three 95-MMBH boilers with ultra-low NOx emissions of 9 ppm, as well as one 4.5-MW natural gas fired turbine CHP with a Heat Recovery Steam Generator (HRSG) sized at 29.2 MMBH unfired and 62.5 MMBH with duct firing.

For increased resiliency, the new site will include redundant interconnections to the existing site 12.47-kV power distribution system. The new 1.75-MW diesel emergency generator will provide backup power to the boiler plant, including the black start of the CHP. The existing USTs will be replaced with AST options sized for seven days of storage during peak heating season. The equipment at B1286 will be replaced with the same new equipment as in Option #1.

This option will cost $90.4 million.

3.1.3 Option #3

Option #3 will decentralize the southwest steam line and convert the facilities that are connected to the steam plant, B260, to natural gas heating systems. In order to be cost effective, Option #3 will provide a savings to investment ratio (SIR that is estimated to be greater than 1.0 and a parametric cost estimate of converting each facility to natural gas heating.

The existing steam to hot water converters will be demolished and replaced with hot water boilers and/or water heaters dependent upon the certain facility. Buildings requiring steam because of Air Handling Unit (AHU) steam coils or kitchen equipment will have small package steam boilers added. Option #3 is equivalent to Option #1 with the addition of the southwest steam loop decentralization. The existing boilers will be replaced with five 50 MMBH units at B260, and two 50-MMBH units at B1286.

This option will cost $50.5 million.

3.1.4 LLC and Annual Cost Savings

Tables 3-1, 3-2, and 3-3 show the initial costs, annual reduction in utility and maintenance costs, and savings to investment ratios for Options #1, #2, and #3 respectively.

Option #1 has an overall initial cost of $46.3 million with an SIR of 0.26.

Option #2 has an overall initial cost of $90.4 million with an SIR of 0.26.

Option #3 has an overall initial cost of $50.5 million with an SIR of 0.25.

Table 3-1: Option #1 LCCA

Building Initial Cost

Gas Savings

Electric

Savings ($) Water

Savings ($) Maintenance Savings ($)

Total Savings ($)

Savings to Investment

Ratio 260 33,001,479 381,490 (37,612)1 293 157,107 501,278 0.30

1286 13,253,817 66,231 (1,318) 51 53,857 118,821 0.17

TOTAL 46,255,295 447,721 (38,930) 344 210,964 620,099 0.26

Table 3-2: Option #2 LCCA

Building Initial Cost

Gas

Savings ($) Electric

Savings ($) Water

Savings ($) Maintenance Savings ($)

Total Savings ($)

Savings to Investment

Ratio 260 77,169,992 (395,973)1 2,070,677 293 (600,347) 1,074,649 0.28

1286 13,253,817 66,231 (1,318) 51 53,857 118,821 0.17

TOTAL 90,423,809 (329,742) 2,069,359 344 (546,490) 1,193,470 0.26

Table 3-3: Option #3 LCCA

Building Initial Cost

($) Gas Savings ($)

Electric Savings

Water Savings

Maintenance Savings ($) Total Savings ($)

Savings to Investment

Ratio 260 33,001,479 381,490 (37,612)1 293 157,107 501,278 0.30

1286 13,253,817 66,231 (1,318) 51 53,857 118,821 0.17

348 338,306 607 - 175 (418) 365 0.00

350 349,712 334 - 94 (474) (46) -0.01

351 343,094 346 - 83 (474) (44) -0.01

356 60,663 170 (1,565) 74 395 (927) -0.27

358 360,152 607 - 175 (418) 365 0.00

385 180,235 192 - 57 (287) (37) -0.01

364 360,342 607 - 175 (418) 365 0.00

430 220,230 632 - 603 (287) 947 0.08

440 65,487 165 - 49 (87) 127 0.01

441 84,428 54 - 16 (87) (17) -0.01

450 202,193 603 - 181 (287) 497 0.01

450B 184,220 101 - 97 (287) (89) -0.01

461 270,437 2298 - 1,742 13 4,053 1.15

519 875,815 322 - 108 (300) 130 0.00

522 313,651 131 - 104 (474) (239) -0.01

TOTAL 50,464,261 454,890 (40,495) 4,079 207,074 625,548 0.25

See Appendix H for detail LCCA calculations.

3.2 CONCEPTUAL DESIGN OPTIONS

Table 3-4 summarizes the evaluation of Options #1, 2, and 3. The table summarizes the pros and cons and indicates the recommended option. These options are discussed in greater detail in the remainder of this report.

Table 3-4: Options Summary

Option Pros Cons Option #1

Replace boilers and upgrade existing boiler plants, B260 and B1286.

No CHP.

Lowest initial cost

Infrastructure in place

Aging boiler and supporting equipment to be replaced

Existing buildings do not meet current design standards and are in poor condition

Equipment phasing and high degree of coordination required to install new boilers in a continuously operating steam plant

Large building openings would be required for new boilers to be installed.

Option #2

New boiler plant at Building 260 with 4.5-MW

CHP

Building 1286 same as Option #1

(Recommended Option)

New building would meet all required standards

CHP would add to basewide microgrid system and resiliency goals

New building would simplify phasing with minimal disruption to operations

All boiler plant equipment replaced

Highest initial cost

New utilities would need to be coordinated and connected to new B260

New B260 would take existing site currently used for storage

Option #3

Same as Option #1, with the decentralization of the facilities that are tied into the southwest steam loop

Reduced heat losses through pipes and traps

Asbestos would be removed in all southwest loop mechanical rooms

Aging equipment replaced

High initial costs for decentralization and only one building has an SIR above 1.0

Some buildings would require additions to mechanical rooms

Shutdowns to tie into existing utilities (water, electricity, HVAC) required

Some buildings will require new routing or upsizing of utility lines from outside of space

Unknown variables and change orders higher

HVAC = heating, ventilation, and air conditioning

3.3 OPTION #1: REPLACE BOILERS IN B260 AND B1286 – NO CHP

3.3.1 Description

Option #1 will include the replacement of the boilers, deaerator and condensate tank, and pumps;

and add heat recovery blow down tanks in B260 and B1286. Modifications to the building will be required to accommodate the new boilers. Figures 3-1 and 3-2 show the new boilers in existing B260 and B1286, respectively.

Figure 3-1: Option #1 – Replace Boilers in Existing B260

Figure 3-2: Option #1 – Replace Boilers at Existing B1286

3.3.2 Anticipated Construction Cost

It is estimated that the Option #1 construction costs will total of $46.3 million.

3.3.3 Anticipated Construction Schedule

The anticipated construction schedule for this project would be approximately 546 days in length depending upon the configuration selected and availability of equipment. A two to three-month commissioning and start-up period would be needed. The actual construction and commissioning duration are subject to a variety of factors, including the level of experience of the selected contractor, weather, etc.

3.4 OPTION #2: NEW B260 WITH CHP AND B1286 BOILER UPGRADE

3.4.1 Description

Option #2 will involve the construction of a new facility for B260, with the construction of “B2XX,” which will include a steam generating CHP facility approximately 300 yards from the southeast corner of the existing steam plant.

At B1286, the boilers will be replaced and the existing building will be upgraded (seismic, etc.), equivalent to Option #1.

Figure 3-3: Option #2 – New B2XX with CHP

3.4.2 Anticipated Construction Cost

It is estimated that the Option #2 construction costs will total $90.4 million.

3.4.3 Anticipated Construction Schedule

The anticipated construction schedule for this project will be approximately 728 days in length, depending upon the configuration selected and availability of equipment. A two to three-month commissioning and start-up period should be anticipated. The actual construction and commissioning duration are subject to a variety of factors, including the level of experience of the selected contractor, weather, etc.

3.5 OPTION #3: DECENTRALIZATION OF SOUTHWEST STEAM LOOP

3.5.1 Description

Option #3 will involve the decentralization of the steam systems at the facilities that are connected to the southwest steam loop (see Table 3-4, above). Currently, all the southwest loop facilities are tied to B260. The LCCA analyzed the feasibility of replacing steam-to-hot water converters and/or steam-heated domestic water storage tanks. New systems will include hot water boilers for heating, ventilation, and air conditioning (HVAC); hot water heaters for domestic use; and packaged steam for buildings requiring it, such as the dining hall, B519.

Additions to some of these buildings or group of buildings may be required. For example, B461 will require a 30 feet by 10 feet addition to accommodate a new hot water boiler to heat the pools. Boiler equipment and the structures at B260 and B1286 will be upgraded, which is equivalent to Option #1.

Figure 3-4: Option #3 – New Pool Building addition

3.5.2 Anticipated Construction Cost

It is estimated that the Option #3 construction costs will total $50.5 million.

3.5.3 Anticipated Construction Schedule

The anticipated construction schedule for this project will be approximately 728 days in length, depending upon the configuration selected and availability of equipment. A two- to three-month commissioning and start-up period would be needed. The actual construction and commissioning duration are subject to a variety of factors, including the level of experience of the selected contractor, weather, etc.

3.6 ARCHITECTURAL CONCEPTUAL DESIGN OPTIONS

Following are illustrations of the proposed new CHP building, “B2XX”. B2XX will house new boilers and a CHP, as well as new administrative and associated spaces. It will be a single story high and accommodate the required square footage on a triangular-shaped site. The building will be fully sprinklered, except for the boiler and electrical rooms. The building, parking, and on-site paths of travel must be compliant with the Architectural Barriers Act of 1968 (ABA). Parking and vehicle circulation will be provided on site. There will also be ASTs for fuel and fenced enclosures for an electrical substation, switchgear, circuit breakers, a generator, and transformers.

The building will have a structural steel frame with steel girts for exterior cladding, consisting of painted insulated sheet metal panels, with a low-slope painted insulated metal panel roof. The CHP unit exhaust stack will be separated from the building proper for structural reasons; it and the boiler stacks will be approximately 70 feet in height. The building will be about 56 feet in height. The roof and stack heights were examined and determined in compiling data from State of Utah’s definition of “vertically unrestricted” under R307-410-2, and “slope ratio” data guidance from AFI13-204V and UFC 3-260-01. The adjacent building is approximately 135 feet from B260, is building 295 and has a measured height of 40 feet. The adjacent building data is indicative for stack measurements.

Several building options were examined, each with specific area and enclosure requirements.

Massing studies were developed with simple 3D models to examine the site and aesthetic ramifications of each for the sites considered viable. Figures 3-5 and 3-6 illustrate the approaches taken and evaluated in the full massing studies for 3D modeling of renovation of existing buildings, B260 and B1286; see also Figures 2-3 and 2-4, respectively.

Figure 3-5: Proposed CHP Building

Figure 3-6: Proposed CHP Building – Elevations

3.7 ELECTRICAL CONCEPTUAL DESIGN OPTIONS

3.7.1 Option #1: Replace Boilers in B260 and B1286, No CHP

This option is based on the replacement of the existing eight boilers with five new boilers in B260 and the replacement of the existing three boilers in B1286 with two new boilers.

In B260, the existing eight boilers would be demolished. Some of the existing equipment is adequately sized to support the new boilers:

The existing 480/277-Volt (V) 1200-Amp service, The 1,000 kilovolt-ampere (kVA) utility transformer, The 1200-Amp automatic transfer switch with bypass, The main distribution panel (MDP), and

The 750-kilowatt (kW) emergency stand-by diesel generator.

The existing 480/277 V panelboards, 208/120 V panelboards, and dry type transformers would remain. The contractor will be required to provide a temporary power generator of approximately 750 kVA for approximately 30 days not more than 180 days, during construction to maintain uninterrupted…