**Resource Report 13 -- Engineering and Design Material**

**AES Sparrows Point LNG Terminal & Mid-Atlantic Express Pipeline**

**TABLE OF CONTENTS**

Page

13.1 Facility Description [15](#facility-description)

13.1.1 Owner, Operator and Principal Contractors
[15](#owner-operator-and-principal-contractors)

13.1.2 Location and Site Information
[16](#location-and-site-information)

13.1.3 LNG Receiving Terminal; Source and Market for Product
[17](#lng-receiving-terminal-source-and-market-for-product)

13.1.4 LNG Receiving Terminal; Storage, Import and Sendout Capacities
and Conditions
[19](#lng-receiving-terminal-storage-import-and-sendout-capacities-and-conditions)

13.1.5 Liquefaction; Source of Feed Gas and Market for Product
[21](#liquefaction-source-of-feed-gas-and-market-for-product)

13.1.6 Base Load Liquefaction; Capacities of Feed Gas, Pretreatment,
Liquefaction, Fractionation Products
[21](#base-load-liquefaction-capacities-of-feed-gas-pretreatment-liquefaction-fractionation-products)

13.1.7 Base Load Liquefaction; Storage, Product Shipping and Sendout
Capacities and Conditions
[21](#base-load-liquefaction-storage-product-shipping-and-sendout-capacities-and-conditions)

13.1.8 Peak Shaving; Source of Feed Gas and Market for Product
[21](#peak-shaving-source-of-feed-gas-and-market-for-product)

13.1.9 Peak Shaving; Capacities of Feed Gas Pretreatment and
Liquefaction
[21](#peak-shaving-capacities-of-feed-gas-pretreatment-and-liquefaction)

13.1.10 Peak Shaving; Storage, Vaporization, Sendout Capacities and
Conditions
[21](#peak-shaving-storage-vaporization-sendout-capacities-and-conditions)

13.1.11 Satellite; Source of LNG and Market for Sendout
[21](#satellite-source-of-lng-and-market-for-sendout)

13.1.12 Satellite; Storage, Vaporization, Sendout Capacities and
Conditions
[21](#satellite-storage-vaporization-sendout-capacities-and-conditions)

13.1.13 LNG Trucking Facilities [21](#lng-trucking-facilities)

13.1.14 List of Major Systems and Components
[21](#list-of-major-systems-and-components)

13.1.15 Design Features [21](#design-features)

13.1.16 Utilities and Services [21](#utilities-and-services)

13.1.17 Safety Features for Containment
[22](#safety-features-for-containment)

13.1.18 Safety Features for Fire Protection
[22](#safety-features-for-fire-protection)

13.1.19 Emergency Response [22](#emergency-response)

13.1.20 Commissioning and Cooldown [22](#commissioning-and-cooldown)

13.1.21 Operations and Maintenance [22](#operations-and-maintenance)

13.1.22 Staffing Structure [22](#staffing-structure)

13.1.23 Future Plans for the LNG Terminal
[22](#future-plans-for-the-lng-terminal)

13.1.24 Drawings [23](#drawings)

13.2 Project Schedule [23](#project-schedule)

13.3 Site Plans [24](#site-plans)

13.3.1 Site Description [24](#site-description)

13.3.2 Drawings [28](#drawings-1)

13.4 Basis of Design [29](#basis-of-design)

13.4.1 Guarantee Conditions [29](#guarantee-conditions)

13.4.2 Site Conditions [29](#site-conditions)

13.4.3 Emissions [30](#emissions)

13.4.4 Seismic [31](#seismic)

13.4.5 Climatic Conditions [31](#climatic-conditions)

13.4.6 Shipping [33](#shipping)

13.4.7 Mooring [33](#mooring)

13.4.8 LNG Cargos [33](#lng-cargos)

13.4.9 Unloading [33](#unloading)

13.4.10 Feed Gas [34](#feed-gas)

13.4.11 Pretreatment [34](#pretreatment)

13.4.12 Regeneration Gas [34](#regeneration-gas)

13.4.13 Liquefaction [34](#liquefaction)

13.4.14 Fractionation Products [34](#fractionation-products)

13.4.15 Storage [34](#storage)

13.4.16 LP Pumps [34](#lp-pumps)

13.4.17 HP Pumps [34](#hp-pumps)

13.4.18 IP Pumps [34](#ip-pumps)

13.4.19 HP Vaporizers [34](#hp-vaporizers)

13.4.20 IP Vaporizers [34](#ip-vaporizers)

13.4.21 Gas Liquid Removal [34](#gas-liquid-removal)

13.4.22 Btu Adjustment [35](#btu-adjustment)

13.4.23 HP Sendout Battery limit [35](#hp-sendout-battery-limit)

13.4.24 IP Fuel Gas Conditions [35](#ip-fuel-gas-conditions)

13.4.25 Vapor Handling [35](#vapor-handling)

13.4.26 Discretionary Vent Stack [35](#discretionary-vent-stack)

13.4.27 Flares [35](#flares)

13.4.28 IP Fuel Gas System [35](#ip-fuel-gas-system)

13.4.29 LP Fuel Gas System [35](#lp-fuel-gas-system)

13.4.30 LNG Trucking [35](#lng-trucking)

13.4.31 Electrical [35](#electrical)

13.4.32 Control Instrumentation [36](#control-instrumentation)

13.4.33 Instrument Air [36](#instrument-air)

13.4.34 Service Air [36](#service-air)

13.4.35 Inert Gas [36](#inert-gas)

13.4.36 Nitrogen [36](#nitrogen)

13.4.37 Fire Water [36](#fire-water)

13.4.38 Cooling Water [37](#cooling-water)

13.4.39 Hydrotest Water [37](#hydrotest-water)

13.4.40 Utility (Service) Water [37](#utility-service-water)

13.4.41 Fire Protection [38](#fire-protection)

13.4.42 Site Security [38](#site-security)

13.5 Major Process Systems [38](#major-process-systems)

13.5.1 Marine [38](#marine)

13.5.2 Unloading [38](#unloading-1)

13.5.3 Feed Gas [38](#feed-gas-1)

13.5.4 Liquefaction [38](#liquefaction-1)

13.5.5 Fractionation [38](#fractionation)

13.5.6 Vapor Handling [39](#vapor-handling-1)

13.5.7 LNG Sendout System [39](#lng-sendout-system)

13.5.8 Gas Liquid Removal [39](#gas-liquid-removal-1)

13.5.9 Btu Adjustment [39](#btu-adjustment-1)

13.5.10 Vent and Flare Systems [39](#vent-and-flare-systems)

13.5.11 Pressure Relief [39](#pressure-relief)

13.5.12 Sendout Metering [39](#sendout-metering)

13.5.13 LNG Product Loading - Marine [39](#lng-product-loading---marine)

13.5.14 LNG Product Loading/Unloading - Trucking
[39](#lng-product-loadingunloading---trucking)

13.5.15 Commissioning Plan [39](#commissioning-plan)

13.6 LNG Storage Tanks [39](#lng-storage-tanks)

13.6.1 General [39](#general)

13.6.2 Tank Foundation [39](#tank-foundation)

13.6.3 Outer Containment [40](#outer-containment)

13.6.4 Inner Containment [40](#inner-containment)

13.6.5 Seismic Loads on Inner and Outer Tanks
[40](#seismic-loads-on-inner-and-outer-tanks)

13.6.6 Wind Loads on Outer Tank [40](#wind-loads-on-outer-tank)

13.6.7 Insulation System [40](#insulation-system)

13.6.8 Tank Instrumentation [40](#tank-instrumentation)

13.6.9 Fittings, Accessories, and Tank Piping
[40](#fittings-accessories-and-tank-piping)

13.6.10 Stairways and Platforms [40](#stairways-and-platforms)

13.6.11 Cryogenic Spill Protection [40](#cryogenic-spill-protection)

13.6.12 Anchorage [40](#anchorage)

13.6.13 Painting [40](#painting)

13.6.14 Tank Lighting and Convenience Receptacles
[40](#tank-lighting-and-convenience-receptacles)

13.6.15 Electrical Grounding [40](#electrical-grounding)

13.6.16 Welding [41](#welding)

13.6.17 Testing and Inspection [41](#testing-and-inspection)

13.6.18 Procedures for Monitoring and Remediating Stratification
[41](#procedures-for-monitoring-and-remediating-stratification)

13.6.19 Tank Secondary Bottom and Corner Protection
[41](#tank-secondary-bottom-and-corner-protection)

13.6.20 Drawings [41](#drawings-2)

13.7 Utilities [41](#utilities)

13.7.1 Instrument Air [41](#instrument-air-1)

13.7.2 Service Air [41](#service-air-1)

13.7.3 Nitrogen [41](#nitrogen-1)

13.7.4 Potable Water [41](#potable-water)

13.7.5 Service Water [41](#service-water)

13.7.6 Storm Water [41](#storm-water)

13.7.7 Wastewater [42](#wastewater)

13.8 Equipment Data [42](#equipment-data)

13.8.1 Equipment List with Design Conditions
[42](#equipment-list-with-design-conditions)

13.8.2 Equipment Data [42](#equipment-data-1)

13.9 Instrumentation [42](#instrumentation)

13.9.1 Description of Control System
[42](#description-of-control-system)

13.9.2 Plant Control and Monitoring System Components
[42](#plant-control-and-monitoring-system-components)

13.9.3 Field Control Instruments [42](#field-control-instruments)

13.9.4 Control Communication and Control Power
[42](#control-communication-and-control-power)

13.9.5 Backup Power Supply [42](#backup-power-supply)

13.9.6 Sample Conditioning, Analyzers and Custody Transfer
[42](#sample-conditioning-analyzers-and-custody-transfer)

13.9.7 Drawings [42](#drawings-3)

13.10 Safety Instrumentation System [42](#safety-instrumentation-system)

13.10.1 Description of the SIS [43](#description-of-the-sis)

13.10.2 SIS Components [43](#sis-components)

13.10.3 Communication and Control Power
[43](#communication-and-control-power)

13.10.4 Backup Power Supply [43](#backup-power-supply-1)

13.10.5 Emergency Shut Down (ESD) [43](#emergency-shut-down-esd)

13.10.6 Drawings and Tables [43](#drawings-and-tables)

13.11 Electrical [43](#electrical-1)

13.11.1 Description of Electrical System
[43](#description-of-electrical-system)

13.11.2 Hazardous Area Classification Basis
[43](#hazardous-area-classification-basis)

13.11.3 Electrical Tables and Lists [43](#electrical-tables-and-lists)

13.11.4 Electrical Drawings [43](#electrical-drawings)

13.12 Fuel Gas [43](#fuel-gas)

13.12.1 Description of Fuel Gas System
[43](#description-of-fuel-gas-system)

13.12.2 Drawings [44](#drawings-4)

13.13 Spill Containment Systems [44](#spill-containment-systems)

13.13.1 Description of Spill Containment Systems
[44](#description-of-spill-containment-systems)

13.13.2 Thermal Radiation Exclusion Zones
[44](#thermal-radiation-exclusion-zones)

13.13.3 Flammable Vapor Exclusion Zones
[44](#flammable-vapor-exclusion-zones)

13.14 Hazard Detection Systems [44](#hazard-detection-systems)

13.14.1 Description of Hazard Detection Systems
[44](#description-of-hazard-detection-systems)

13.14.2 Description of Hazard Warning Systems Including Offsite, Plant
Wide and Local Area
[44](#description-of-hazard-warning-systems-including-offsite-plant-wide-and-local-area)

13.14.3 Hazard Detector List [44](#hazard-detector-list)

13.14.4 Drawings [44](#drawings-5)

13.15 Fire Suppression and Response Plan
[44](#fire-suppression-and-response-plan)

13.15.1 ERP Development [44](#erp-development)

13.15.2 ERP Schedule [44](#erp-schedule)

13.16 Hazard Control Systems [45](#hazard-control-systems)

13.16.1 Description of Hazard Control Equipment and Systems
[45](#description-of-hazard-control-equipment-and-systems)

13.16.2 Dry Chemical Basis of Design [45](#dry-chemical-basis-of-design)

13.16.3 Matrix of Hazard Control Equipment
[45](#matrix-of-hazard-control-equipment)

13.16.4 Dry Chemical System Drawings [45](#dry-chemical-system-drawings)

13.17 Fire Water [45](#fire-water-1)

13.17.1 Description of Fire Water System
[45](#description-of-fire-water-system)

13.17.2 Matrix of all Fire Water Delivery Equipment
[45](#matrix-of-all-fire-water-delivery-equipment)

13.17.3 Fire Water Drawings [45](#fire-water-drawings)

13.18 High Expansion Foam System [45](#high-expansion-foam-system)

13.18.1 Description of Foam System and Equipment
[45](#description-of-foam-system-and-equipment)

13.18.2 Foam System Basis of Design [45](#foam-system-basis-of-design)

13.18.3 Matrix with Tag Number, Location, Type/Model of Foam Equipment.
[45](#matrix-with-tag-number-location-typemodel-of-foam-equipment.)

13.18.4 Drawings [46](#drawings-6)

13.19 Security [46](#security)

13.19.1 Security Description [46](#security-description)

13.19.2 Site Access Control [46](#site-access-control)

13.19.3 Cameras [46](#cameras)

13.19.4 Intrusion Detection [46](#intrusion-detection)

13.20 Piping [46](#piping)

13.20.1 Piping Systems [46](#piping-systems)

13.20.2 Piping Specification [46](#piping-specification)

13.20.3 Piping Insulation, Cold [46](#piping-insulation-cold)

13.20.4 Piping Insulation, Hot [46](#piping-insulation-hot)

13.20.5 Pipe Racks [46](#pipe-racks)

13.20.6 Piping Specification Tabular Summary
[46](#piping-specification-tabular-summary)

13.20.7 Piping Insulation Tabular Summary
[47](#piping-insulation-tabular-summary)

13.20.8 Pipe Rack and Piping Arrangement Drawings
[47](#pipe-rack-and-piping-arrangement-drawings)

13.21 Foundations and Supports [47](#foundations-and-supports)

13.21.1 Description of Foundations and Supports
[47](#description-of-foundations-and-supports)

13.21.2 Drawings [47](#drawings-7)

13.22 Buildings and Structures [47](#buildings-and-structures)

13.22.1 Description of Buildings [47](#description-of-buildings)

13.22.2 List of Buildings with Dimensions
[47](#list-of-buildings-with-dimensions)

13.22.3 Drawings [47](#drawings-8)

13.23 Process Drawings [47](#process-drawings)

13.23.1 Process Flow Diagrams and Material and Energy Balances
[47](#process-flow-diagrams-and-material-and-energy-balances)

13.24 Piping and Instrument Diagrams
[47](#piping-and-instrument-diagrams)

13.24.1 Drawing List with Revision Number and Issue Date
[47](#drawing-list-with-revision-number-and-issue-date)

13.24.2 Piping and Instrumentation Legend and Symbols
[47](#piping-and-instrumentation-legend-and-symbols)

Table ‎13.1.3 LNG Sources and Compositions
[17](#__RefHeading___Toc156025305)

Table 13.3.2.2 Plot Plans and Site Plan
[29](#__RefHeading___Toc156025306)

Table ‎13.4.2.6 Site Tidal Elevations [30](#__RefHeading___Toc156025307)

Table ‎13.1 Anticipated Flood Elevations
[33](#__RefHeading___Toc156025308)

  -------------------------------------------------------------------------
  **Term**        **Description**
  --------------- ---------------------------------------------------------
  \"              inches

  °F              degree Fahrenheit

  §               Section

  AMSC            Area Maritime Security Committee

  ANSI            American National Standards Institute

  AOR             Area of Responsibility

  API             American Petroleum Institute

  ASME            American Society of Mechanical Engineers

  ATWS            Additional Temporary Workspace

  bbl             barrels

  bbl/h           barrels per hour

  bgs             Below ground surfaces

  BIA             Bureau of Indian Affairs

  BIBI            Benthetic index of biotic integrity

  BMP             Best Management Practice

  BMS             Burner Management System

  BOG             boiloff gas

  Bscfd / bscfd   billion standard cubic feet per day

  Btu             British thermal unit

  Btu/(ft^2^hr)   British thermal unit per feet squared per hour

  C5 plus         pentane plus

  CCTV            closed circuit television

  CEQ             Council on Environmental Quality

  CFR             Code of Federal Regulations

  CO              carbon monoxide

  COE             U.S. Army Corps of Engineers

  COMAR           Code of Maryland Regulations

  COTP            Coast Guard Captains of the Port

  CROW            Construction right-of-way

  CUM             cubic meter

  CWA             Clean Water Act

  cy              cubic yard

  CZMA            Coastal Zone Management Act of 1972

  DB&B            double block and bleed

  DCS             distributed control system

  DMRF            Dredge Material Recycling Facility

  Dth/day         Decatherms per day

  EA              Environmental Assessment

  EIA             Energy Information Administration

  EIS             Environmental Impact Statement

  EPC             Engineering, Procurement and Construction

  ER              Environmental Report

  ERC             emergency release coupling

  ESA             Endangered Species Act of 1973

  ESD             emergency shutdown

  ESD-1           Pier Emergency Shutdown

  ESD-1-1         Activation of the unloading arm/vapor return arm ERCs on
                  Berth 1 and Berth 2

  ESD-2           Total Terminal Emergency Shutdown

  FAA             Federal Aviation Administration

  FBE             Fusion-Bonded Epoxy

  FEED            Front End Engineering Design

  FERC            Federal Energy Regulatory Commission

  FERC's Plan     FERC's Upland Erosion Control, Revegetation, and
                  Maintenance Plan

  FERC's          FERC's Wetland and Waterbody Construction and Mitigation
  Procedures      Procedures

  FM              Factory Mutual

  fps             feet per second

  ft              feet

  gpm             gallons per minute

  h               hour(s)

  H&MB            heat and material balance

  HAZID           Hazard Identification

  HAZOP           Hazard And Operability

  HDD             Horizontal Direction Drilling

  HDMS            Hazard Detection and Mitigation System

  HHV             higher heating value

  HID             High Intensity Discharge

  HIPPS           High Integrity Pipeline Protection System

  HP              high pressure

  hp              horsepower

  HTF             heat transfer fluid

  IESNA           Illuminating Engineering Society of North America

  in              inch

  inches H~2~O    inches of water

  inches Hg       inches of mercury

  inches Hg/h     inches of mercury per hour

  IP              intermediate pressure

  ISC             International Ship to Shore Connections

  ISO             International Organization for Standardization

  Kts             knots

  kV              kilovolt

  kVA             kilovolt Ampere (one thousand Volt Amperes)

  LDC             Local Distribution Company

  LFL             lower flammability limit

  LHV             lower heating value

  LNG             Liquefied Natural Gas

  LNG Terminal    Sparrows Point LNG Import Terminal

  LOI             Letter of intent

  LP              low pressure

  LTD             Level, Temperature, Density

  M&R             Metering and Regulator

  m^3^            cubic meters

  m^3^/hour       cubic meters per hour

  MAOP            Maximum Allowable Operating Pressure

  mbar            millibar

  mbar/hour       millibar per hour

  MCC             Motor Control Center

  mcf             million cubic feet

  MCMERG          Mid-Chesapeake Marine Emergency Response Group

  MCR             Main Control Room

  MDE             Maryland Department of the Environment

  MDNR            Maryland Department of Natural Resources

  mg/l            Microgram per Liter

  MIS             Management Information System

  MLLW            mean lower low water

  MLV             Mainline valve

  MMBtu/hr        million British thermal units per hour

  MMcf/day        million cubic feet per day

  MMscfd          million standard cubic feet per day

  MP              Milepost

  mph             miles per hour

  MW              megawatt

  N/A             not applicable

  NAS Pax River   Naval Air Station Patuxent River

  NAVD            North American Vertical Datum

  NDE / NDT       Nondestructive Examination / Nondestructive Testing

  NEC             National Electrical Code

  NEPA            National Environmental policy Act of 1969

  NFPA            National Fire Protection Association

  NGA             Natural Gas Act

  NGA / NGPA      Natural Gas Act / Natural Gas Policy Act

  NHPA            National Historic Preservation Act of 1969

  NMFS            National Marine Fisheries Service

  No. ins         number of inches

  NOAA            National Oceanic and Atmospheric Administration

  NOI             Notice of Intent

  NOx             nitrogen oxides

  NPDES           National Pollutant Discharge Elimination System

  NPL             National Priority List

  NPS             National Park Service

  NRCS            Natural Resources Conservation Service

  NRHP            National Register of Historic Places

  NSA             Noise Sensitive Area

  NTP             Notice to Proceed

  NVIC            Navigation and vessel Inspection Circular

  NWI             National Wetland Inventory

  O&M             Operations And Maintenance

  OBE             Operating Basis Earthquake

  OD              Outside Diameter

  OSHA            Occupational Safety and Health Administration

  P&ID            piping and instrumentation diagram

  PAH             Poly Aromatic Hydrocarbon

  PCB             Polychlorinated Biphyenyls

  PCMS            Plant Control and Monitoring System

  PCR             Platform Control Room

  PDEP            Pennsylvania Department of Environmental Protection

  PDM             Processed Dredged Material

  PIANC           Permanent International Association Navigation Congress

  PLC             Programmable Logic Controller

  PM              particulate matter

  POTW            Publicly-owned Treatment Works

  PPB / ppb       parts per billion

  PPM / ppm       parts per million

  PPT / ppt       Parts per trillion

  psf             pounds per square foot

  psig            pounds per square inch gauge

  PVC             Poly Vinyl Chloride

  PWSA            Preliminary water way suitability assessment

  QA              Quality Assurance

  QC              Quality Control

  RGS             Rigid Galvanized Steel (conduit)

  ROW             Right-of-Way

  RR              Resource Report

  RTD             resistance temperature detector

  RTU             remote terminal unit

  RUSLE           Revised Universal Soil Loss Equation

  SAV             Aquatic vegetation

  SCADA           Supervisory Control and Data Acquisition

  scfh            standard cubic foot (feet) per hour

  scfm            standard cubic foot (feet) per minute

  SCUBA           Self-contained Underwater Breathing Apparatus

  SHPO            State Historic Preservation Officer

  SIP             State Implementation Plan

  SIS             Safety Instrumented System

  SPCC            Spill Prevention, Control, and Countermeasure

  SSE             Safe Shutdown Earthquake

  SSURGO          Soil Survey Geographic

  STATSCO         State Soil Geographic

  SWPPP           Storm Water Pollution Prevention Plan

  Tcf             Trillion Cubic Feet

  TCP/IP          Transmission Control Protocol/Internet Protocol,

  THPO            Tribal Historic Preservation Office

  TMDL            Total Maximum Daily Load

  TOC             Total organic carbon

  Trap            Pig Launcher Receiver Facility

  UL              Underwriters Laboratories

  UPS             Uninterruptible Power Supply

  USCG            United States Coast Guard

  USDA            United States Department of Agriculture

  USDOE           United States Department of Energy

  USDOT           United States Department of Transportation

  USEPA / EPA     United States Environmental Protection Agency

  USFWS           U.S. Fish and Wildlife Service

  usg             United States gallons

  usgpm           United States gallons per minute

  USGS            U.S. Geological Survey

  V               voltage

  VOC             volatile organic compound

  WSA             Water way suitability assessment

  WWTP            Waste Water Treatment Plant
  -------------------------------------------------------------------------

##  {#section .unnumbered}

##  {#section-1 .unnumbered}

## Facility Description

### Owner, Operator and Principal Contractors

AES Sparrows Point LNG, LLC (Sparrows Point LNG) proposes to construct,
own, and operate a new liquefied natural gas (LNG) import, storage, and
regasification terminal (LNG Terminal) at the Sparrows Point Industrial
Complex situated on the Sparrows Point peninsula east of the Port of
Baltimore in Maryland. LNG will be delivered to the LNG Terminal by LNG
marine vessels, offloaded from these vessels to shoreside storage tanks,
regasified to natural gas on the LNG Terminal site (Terminal Site), and
the regasified natural gas transported to consumers by pipeline. The LNG
Terminal will have a regasification capacity of 1.5 billion standard
cubic feet of natural gas per day (bscfd), with the potential to expand
to 2.25 bscfd. Regasified natural gas will be delivered to markets in
the Mid-Atlantic Region and northern portions of the South Atlantic
Region through an approximately 88-mile, 30-inch outside diameter
interstate natural gas pipeline (Pipeline) to be constructed and
operated by Mid-Atlantic Express, L.L.C. (Mid-Atlantic Express). The
Pipeline will extend from the LNG Terminal to points of interconnection
with existing interstate natural gas pipeline systems near Eagle,
Pennsylvania. Together the LNG Terminal and Pipeline projects are
referred to as the Sparrows Point Project or Project. Both Sparrows
Point LNG and Mid-Atlantic Express (hereinafter collectively referred to
as AES) are subsidiaries of The AES Corporation.

The Project footprint is located in the counties of Baltimore, Harford,
and Cecil in Maryland and the counties of Lancaster and Chester in
Pennsylvania. The Terminal Site, which is located entirely within
Baltimore County, is a parcel located within a former shipyard. The
route proposed for the Pipeline (Pipeline Route), which crosses all of
the listed counties, includes industrial, commercial, agricultural, and
residential lands. Together, the Terminal Site and the Pipeline Route
comprise the Project Area.

As described in Section 1.10 of Resource Report 1, *General Project
Description*, The AES Corporation is considering the possibility of
building a combined cycle cogeneration power plant (Power Plant) on the
Terminal Site. The Power Plant would be configured with one F-Class
combustion gas turbine, one steam turbine, and associated auxiliaries.
The Power Plant would operate only on natural gas and would produce
approximately 300 megawatts (MW) of clean electric power within an area
of high energy demand. The Power Plant would be connected to the local
utility electric system by an overhead electric power transmission line.

### Location and Site Information

#### Location

The LNG Terminal will be located on an approximately 80-acre parcel
within the existing Sparrows Point Industrial Complex located in
Baltimore County, Maryland, with approximately 45 acres of upland area
and the remainder of the Terminal Site near a shore riparian rights
area. The Sparrows Point Shipyard is situated on a promontory that
extends into the Chesapeake Bay east of the Port of Baltimore. More
specifically, the Terminal Site is located on the Marine Channel
adjacent to the Fort McHenry channel near the confluence of the Fort
McHenry Channel and the Brewerton Angle. Drawing 06903-DG-000-002 in
Appendix U.1 shows the location of the Terminal Site.

Drawing 06903-DG-000-001 included in Appendix U.1 shows the potential
location of the Power Plant.

#### Site Information

The Terminal Site previously was owned and operated by Bethlehem Steel
Corporation as a steel manufacturing and shipbuilding facility. AES has
established a lease agreement with SPS Limited Partnership, LLLP, owners
of the Sparrows Point Shipyard, for the 80-acre parcel where the LNG
Terminal is to be located.

Demolition of selected existing structures at the Terminal Site will be
needed to prepare the site for construction. The shipyard formerly
consisted of ten marine slips used for ship construction and/repair.
Slips No. 1 through No. 5 are now demolished, and the area they occupied
is at a common grade. Portions of the remaining slips (No. 6 through No.
10) are used for hauling out and dismantling barges. All slip structures
currently remaining on shore will be demolished and the associated area
leveled to common grade should the Project be approved and constructed.

Behind these slips to the east, the Terminal Site contains two large
buildings: a metal sided structure (known as the "Panel Building") and
masonry structure (the "Fabrication Building"). The Panel Building will
be demolished and the Fabrication Building will be refurbished and used
to house certain auxiliary and utility equipment, and the control room
and administrative services associated with the LNG Terminal. The
Fabrication Building will also be used to house the Power Plant,
including associated administrative and maintenance operations, should
that facility be constructed.

A new shoreward bulkhead line will be established to straighten out the
waterfront. Existing finger piers and low-level relieving platforms that
lie offshore of the new bulkhead alignment will be removed as required.

Once the new bulkhead is established, additional fill may be added to
the site to bring it to a consistent grade. Fill to bring the site to
grade could be obtained from the processed dredge material, pending
determination of engineering properties and match of schedule between
the dredge operation and initial terminal construction.

### LNG Receiving Terminal; Source and Market for Product

#### LNG Source

The LNG Terminal has been designed to receive LNG from several possible
LNG production sources. A range of compositions has been used for the
design basis. The typical case is used for process simulation purposes,
but equipment is rated to accommodate both light and heavy compositions
as illustrated in Table 13.1.3.1. The design of the LNG Terminal does
not require energy content control (Btu control) of the sendout natural
gas.

[]{#__RefHeading___Toc156025305 .anchor}Table 13.1.3 LNG Sources and
Compositions

  ---------------------------------------------------------------------------
                                    Light LNG     Heavy (Note)  Typical LNG
  -------------------- ------------ ------------- ------------- -------------
  Component            Units        Composition   Composition   Composition

  Source                            Trinidad      Oman          Nigeria

  Methane              Mol %        96.27         87.00         92.9

  Ethane               Mol %        3.17          8.11          4.6

  Propane              Mol %        0.42          3.13          1.9

  n-Butane             Mol %        0.04          0.81          0.23

  i-Butane             Mol %        0.05          0.79          0.24

  Pentanes and higher  Mol %        0.01          0.05          0.004

  Nitrogen             Mol %        0.04          0.11          0.086

  Molecular Weight                  16.65         18.77         17.43

  Gross Heating Value  Btu/scf      1042.4        1155.2        1085

  Gas Specific Gravity Air = 1.00   0.575         0.646         0.600

  H~2~S                ppm by vol.  nil           Nil           nil

  Total Sulfur         ppm          nil           Nil           nil

  Mercaptan Sulfur     ppb          nil           Nil           nil
  ---------------------------------------------------------------------------

Note: "Heavy" LNG has been used for sizing LNG equipment. Not related to
pipeline tariff compositional or heating value limitations.

#### Natural Gas Market

Energy demand in the United States continues to grow at a relatively
constant pace. According to the U.S. Energy Information Administration
(EIA 2006), total energy consumption in the United States is projected
to increase by 27 percent by the year 2025 (1.2 percent annually), from
100 quadrillion British thermal units (Btu)/year in 2004 to 127
quadrillion Btu/year in 2025. The EIA predicts that the projected growth
in energy demand (from present to 2025) will vary by fuel type. Demand
for coal and petroleum is expected to increase, with coal projected to
increase steeply in the years beyond 2020. Demand for natural gas is
projected to continue with strong growth through to 2020, after which it
is expected to level off.

Most importantly, natural gas has increasingly become the fuel of choice
in the United States. According to the EIA, there are a number of
underlying conditions that characterize the U.S. gas market, including:

-   Increased gas demand driven by 200 gigawatts of installed gas-fired
    generation investment since 1999, with limited amounts of
    alternative fuel capability;

-   Declines in domestic gas production throughout the lower 48 states
    and in offshore areas that are in control of the United States;

-   Increased gas imports from Canada nearing current maximum capacity;

-   Decreased gas supply deliverability in the current transportation
    infrastructure;

-   Declines in the demand destruction that began during the sustained
    high price environment; and

-   Stabilization of gas demand due to the rebound in the U.S. economy
    beginning in 2003.

These conditions have led to supply constraints and a steadily
increasing gas price floor, well above pre-2000 historical levels of
below \$3.00/thousand cubic feet (mcf) gas. The North American natural
gas industry will face a critical period over the next 10 to 15 years,
when increased supply availability will be essential. Inevitably,
failure to increase supply to domestic markets will lead to sustained
and higher prices unless new sources of natural gas supply, including
LNG, are developed and delivered to the market via import terminals and
associated pipeline facilities.

The need for incremental sources of natural gas supply to meet growing
demand is particularly acute in the Mid-Atlantic Region and surrounding
regions of the United States due to distances from existing production
areas and limited pipeline capacity from those production areas. The
Sparrows Point Project will provide incremental gas supply directly into
the Mid-Atlantic Region, an area of acute need. The Mid-Atlantic Region
consists of New Jersey, Pennsylvania, Maryland, Delaware, the District
of Columbia, the southern parts of New York, and the northern parts of
Virginia. Baltimore is within the Mid-Atlantic Region and will receive
the benefits associated with the incremental source of natural gas
either through direct supply or displacement. The northern portions of
the South-Atlantic Region that will also benefit from the incremental
source of natural gas from the Project include the southern parts of
Virginia and the northern parts of North Carolina. The benefits in the
northern portions of the South-Atlantic Region will be realized
primarily through displacement rather than direct supply.

Natural gas demand for the Mid-Atlantic Region, the area that will be
most directly served by the Project, was approximately 2.4 trillion
cubic feet (Tcf) in 2005, representing approximately 11 percent of total
U.S. natural gas consumption. Natural gas demand for the Mid-Atlantic
Region has remained between 2.3 Tcf and 2.5 Tcf over the last 10 years
(i.e., 1995 to 2005), as shown in Figure 1.2-2 of Resource Report 1 -
*General Project Description*. The EIA (EIA 2006) is projecting an
approximate 1.3 percent compounded annual growth rate in natural gas
demand for the Mid-Atlantic Region from 2005 to 2020, which will result
in an increase from 2.4 Tcf in 2005 to 2.9 Tcf in 2020. For the period
between 2020 and 2030, EIA has forecasted a modest decline in natural
gas demand to 2.8 Tcf feet in 2030. Natural gas demand from the electric
power generation and commercial segments has shown the most growth for
the period 1995 to 2005. As shown in Figure 1.2-4 of Resource Report 1 -
*General Project Description*, EIA projects that natural gas demand from
electric power generation will continue to show the most significant
growth for the period 2005 to 2030.

Due to its location in the heart of an area of high (and increasing)
natural gas demand, the Project will result in a more reliable and
cost-effective supply of gas to its target markets than gas supplies
from the Gulf of Mexico or other domestic regions of production that
would require significant pipeline expansion to provide the equivalent
amount of natural gas to this market. Introduction of a new source of
supply will have the effect of reducing the "basis" (that is,
differential between index prices for delivered gas in a given market
and the index for prices in a supply region such as the Henry Hub prices
of natural gas) in the market intended to be served by the Project. The
Project will serve a need for additional natural gas by providing a new
supply of LNG. While the LNG supplier will dictate many of the terms of
delivery, natural gas will be supplied directly into the market area.
AES expects the LNG delivered to the LNG Terminal will be priced at
various market index price points, thus being priced competitively with
alternative supplies at these points.

### LNG Receiving Terminal; Storage, Import and Sendout Capacities and Conditions

#### LNG Import Facilities

The following provides a summary of the LNG Terminal facilities,
capacities and conditions:

LNG ship size range 125,000 to 217,000 cubic meters (m^3^)

Number of berths 2

Liquid unloading arms and size per berth 3 x 16 inches

Vapor return arms and size per berth 1 x 16 inches

Unloading maximum rate 12,500 m^3^/hour

Unloading (transfer) pipeline diameter 32 inches

Unloading minimum pressure at ship manifold 100 meter head (65 psig)

Max allowable saturation pressure of ship\'s cargo (equilibrium
pressure) 2.5 psig

Design pressure, arms 150 psig

Design pressure, unloading piping 275 psig

Design vapor return pressure at ship manifold 1.45 psig

Maximum vapor return temperature at ship manifold -180°F

The maximum required vapor flow returned to the ship is to be based on a
normal boiloff rate from the ship. A design rate of 0.15 percent of the
full contents per day at an industry standard of 95°F ambient for newer
ships, and a maximum boiloff rate of 0.25 percent of the full contents
per day at the same 95°F ambient for older ships, is used in the design.

#### LNG Storage

The following provides a summary of the LNG storage capacities and
conditions:

Type of tank Full Containment Above Ground

Foundation Piled with concrete pile cap

Secondary containment Concrete Outer Containment

Number of tanks 3 (design), 4 (expansion)

Gross capacity per tank Approximately 170,000 cubic meters

Working capacity per tank 160,000 cubic meters

Design pressure 4.3 psig

Design temperature -270°F

Discretionary vent pressure 4.0 psig

Design vacuum 0.073 psi below atmospheric pressure

Working pressure 4.3 psig (maximum allowable)

Normal operating pressure range 0.5 -- 3.7 psig

Boiloff rate (pure methane and full tank) 0.05% per day at 95°F ambient

Maximum design LNG density 29.3 lb/ft^3^

#### Natural Gas Sendout

The following provides a summary of the natural gas sendout capacities
and conditions:

Sendout pipeline length Approximately 88 miles

Sendout pipeline diameter (leaving site) 30-inch outside diameter

Design flow rate 1,500 million standard cubic feet per day (MMscfd)

Design flow rate (expansion) 2,250 MMscfd

Maximum pressure vaporizer outlet 2,130 psig

Pipeline maximum allowable operating pressure at battery limit 2,080
psig

Maximum allowable pipeline temperature at battery limit 120°F

Minimum allowable pipeline temperature at battery limit 40°F

Natural gas will flow from the LNG Terminal via the Pipeline to
interconnections with three existing natural gas pipeline systems near
Eagle, Pennsylvania.

### Liquefaction; Source of Feed Gas and Market for Product {#liquefaction-source-of-feed-gas-and-market-for-product .Style-Heading-3-+-Arial-10-pt}

Not applicable

### Base Load Liquefaction; Capacities of Feed Gas, Pretreatment, Liquefaction, Fractionation Products

Not applicable

### Base Load Liquefaction; Storage, Product Shipping and Sendout Capacities and Conditions

Not applicable

### Peak Shaving; Source of Feed Gas and Market for Product

Not applicable

### Peak Shaving; Capacities of Feed Gas Pretreatment and Liquefaction

Not applicable

###  Peak Shaving; Storage, Vaporization, Sendout Capacities and Conditions

Not applicable

###  Satellite; Source of LNG and Market for Sendout

Not applicable

###  Satellite; Storage, Vaporization, Sendout Capacities and Conditions

Not applicable

###  LNG Trucking Facilities

Not applicable

###  List of Major Systems and Components

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Design Features 

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Utilities and Services

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Safety Features for Containment

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Safety Features for Fire Protection

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Emergency Response

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Commissioning and Cooldown

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Operations and Maintenance

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Staffing Structure

The LNG Terminal will be operated on a permanent 24-hour basis and will
be staffed accordingly.

During commercial operations, it is expected that the LNG Terminal will
employ approximately 44 full-time permanent personnel in administration,
security, and O&M areas. The proposed organization chart for the LNG
Terminal is included in Appendix A.1

###  Future Plans for the LNG Terminal

AES may seek to expand the Project in the future through the addition of
a fourth LNG storage tank (T-201D) and expanded high pressure LNG
sendout capacity. Certain engineering elements associated with the
possible future expansion have already been incorporated into the front
end engineering design (FEED) for the LNG Terminal. These include:

-   Common process and auxiliary system piping headers that would have
    to carry the increased volume have been sized accordingly.

-   Double block and bleed (DB&B) isolation has been provided for the
    addition of T-201D and additional HP Pumps and HP Vaporizers that
    will preclude the need to shutdown the LNG Terminal to make tie-ins
    in the future.

-   The geotechnical characteristics of the Terminal Site at the
    location of T-201D will be determined in advance. If a piled
    foundation is necessary for this location, the piles will be
    installed in advance.

-   Additional capacity in the electrical design has been provided.

This future plan is dependent upon market demand and an LNG shipping
availability study that investigates the impacts of local marine weather
and oceanography on ship scheduling.

###  Drawings 

#### Area Location Map

Drawing 06903-DG-000-002 in Appendix U.1 shows the location of the LNG
Terminal.

#### Plot Plan

Drawing 06903-DG-000-001 in Appendix U.1 shows the plot plan.

#### Organization Plan

Appendix A contains an organization chart for the LNG Terminal.

## Project Schedule

A Gantt chart of the proposed Project schedule is included in Appendix
B. The Gantt chart provides details of the engineering, procurement,
construction and startup of the LNG Terminal. Milestones are also
included for filing requirements, FERC approvals and key inspection
points.

The schedule is based on the following assumptions by AES:

-   FERC will issue the Draft EIS on May 8, 2007.

-   FERC will issue the Final EIS on September 27, 2007.

-   FERC will issue the final certificate on November 8, 2007.

-   The balance of permits will be issued by February 2008.

-   AES will award an EPC contract by March 2008.

-   No site work or purchasing of any equipment will be performed until
    the balance of permits and the FERC certificate are issued.

-   Site work is assumed to start when full Notice to Proceed (NTP) is
    issued in June 2008. This will mark the start of site preparation
    for the tanks and Balance of Plant (BOP), and the marine facility.

The LNG tank construction will determine the duration of the
construction of the LNG Terminal. During the tank construction, the BOP
and the marine facility will be constructed in parallel and made ready
for commissioning.

During site construction, the site area will be prepared for the future
installation of a fourth tank, and piles will be installed, to avoid
future disruption when commercial operation starts with the first three
tanks.

After construction and mechanical completion of the first LNG storage
tank, the LNG Terminal will be cooled down and started up, and
performance testing will be completed. The LNG Terminal will goes into
commercial operations with the first tank in December 2010.

Final completion will occur after the second and third tanks are placed
in service. One month after the third tank is placed in service, the
punch list will be completed and the Contractor will achieve Final
Completion for owner acceptance, with the terminal in-service with all
three tanks. The date of Final Completion is scheduled to be May 2011.

## Site Plans

### Site Description

#### Location

The LNG Terminal will be located on an approximately 80-acre parcel
within the existing Sparrows Point Industrial Complex located in
Baltimore County, Maryland, with approximately 45 acres of upland area
and the remainder of the Terminal Site near a shore riparian rights
area. The Sparrows Point Shipyard is situated on a promontory that
extends into the Chesapeake Bay east of the Port of Baltimore. More
specifically, the Terminal Site is located on the Marine Channel
adjacent to the Fort McHenry channel near the confluence of the Fort
McHenry Channel and the Brewerton Angle.

#### Site Development

Sparrows Point LNG proposes to construct, own, and operate the LNG
Terminal at the Sparrows Point Industrial Complex situated on the
Sparrows Point peninsula. The proposed development will consist of three
LNG tanks, with the possibility of a fourth tank being constructed in a
later phase. The development will also include process equipment needed
to vaporize the LNG and handle BOG.

Demolition of selected structures at the existing Terminal Site will be
needed to prepare the site for construction. The shipyard formerly
consisted of 10 slips used for ship construction and/repair. Slips Nos.
1 through 5 are demolished and the area they occupied is at a common
grade. Portions of the remaining slips (Nos. 6 through 10) are used for
hauling out and dismantling barges. Behind these slips to the east, the
site contains two large buildings, the Panel Building and the
Fabrication Building.

For development of the LNG Terminal, the remaining on-shore slip
structures will be demolished and the associated area leveled to the
site's common grade.

The Panel Building will also be demolished. A new shoreward bulkhead
line will be established to straighten out the waterfront -- which is
further described below. Existing finger piers and low-level relieving
platforms that lie offshore of the new bulkhead alignment will be
removed as required. This demolition will result in the opening up of
previously disturbed marine bottom.

The proposed marine facilities will consist of two berths for LNG ships.
The tug support will be provided by existing tug operators in the
Baltimore port area and no tug berthing is planned at the facility. The
construction process will include the rehabilitation of existing Pier 1
at the site, installation of an elevated unloading platform and the
installation of an elevated pipeway and associated spillway.

Pier rehabilitation will include the concrete encasement, and/or
splicing of the existing piles, repairs to the concrete cap, and
repairs/resurfacing of the existing concrete deck. The repairs to the
piles and caps will take place from floating construction barges. The
floating construction barges provide the ability to be repositioned as
required in the working area in order to provide uninhibited access to
the items being repaired, ensuring proper construction techniques can be
used.

Pre-cast concrete elements for the unloading platform, pipeway and
associated spillway, will be set into place via crane, which will be
located either on floating construction barges or the existing pier,
pending space availability. The floating construction barges will be
anchored into place with spud piles. These construction barges provide
the ability to be repositioned as required in the working area in order
to provide uninhibited access to the item under construction, ensuring
proper construction techniques can be utilized.

The cast-in-place concrete elements, to support the deck rehabilitation,
unloading platform, pipeway and associated spillway will be constructed
from floating construction barges or landside, as space allows. As noted
for the precast elements and pier repairs, floating construction barges
provide the ability to be repositioned as required in the working area
in order to provide uninhibited access to the item under construction,
ensuring proper construction techniques can be utilized.

Once the rehabilitation of the pier deck has been completed, the
elevated steel structure will be built to support the unloading
platform, pipeway and spillway. This construction will take place from
the land side; however, the final setting of the unloading and vapor
return arms will take place from a construction work barge.

A king pile steel sheet pile bulkhead will be installed along the
western limits of the upland facility to help protect the site from
potential flood concerns. The steel sheets will be driven with either a
vibratory or impact pile driving hammer. Where accessible, the piles
will be driven from land based rig. In locations where access is from
the waterside only, the piles will be driven by a rig based on a
floating construction barge. The barge can be anchored into location
with spud piles, if necessary, to provide a stable working area.
Templates will be used to ensure that the sheet piles are driven in the
proper location and that plumbness is maintained within acceptable
limits.

Once the new bulkhead is established, additional fill may be added to
the site to bring it to a consistent grade. Fill to bring the site to
grade will be obtained from the processed dredge material, pending
determination of engineering properties, or selected commercial sources,
as may be needed to match schedule of initial terminal construction.

The structures associated with the on-shore portion of the LNG terminal
include the existing Fabrication Building, which will be refurbished to
house the control room, administrative functions, auxiliary equipment
and utilities; the Compressor Building; and various other structures
(fire pump houses, security building, etc.), and the potential Power
Plant, much of which will be located inside the existing Fabrication
Building. Refurbishment of the Fabrication Building will include
repair/replacement of portions of the roof, removal of hazards, and
repair of interior foundations. Other site buildings will be new
construction, and will be constructed in accordance with code
requirements commensurate with their function. Where permitted,
buildings will be constructed on concrete slabs and provided with metal
frames and metal siding.

#### Soil and Site Preparation

General

During construction, where excavation is required to reach design
subgrade level, the final subgrade exposed after excavating will be
proof-rolled. Areas that show signs of movement, rutting, or instability
will be undercut to competent material, to a maximum depth of 2 ft or to
suitable subgrade soils, whichever is shallower, and replaced with
structural fill. At the undercut depth, if the area continues to show
signs of instability, geogrid and compacted AASHTO No. 57 stone, or MDOT
Graded Aggregate Base or other approved material will be placed to
achieve a stable working mat for fill placement. Similarly, where
filling is required to reach design subgrade level, the existing ground
surface will be cleared of all unsuitable material (deleterious
material) and proof-rolled. During construction, temporary dewatering of
excavations that extend below groundwater level may be necessary.
Dewatering will be performed by pumping standing water from temporary
sumps within the excavation, or from installed wellpoints in close
proximity to excavations. Water generated from dewatering will be tested
for quality and managed consistent with construction and water discharge
regulatory requirements.

Appendix T contains specifications for typical civil construction work
for the site.

Pavements

Prior to construction of proposed pavements, existing pavements and
slabs-on-grade will be removed from the proposed pavement areas and the
soils excavated down to the propose pavement subgrade level. Existing
foundations and concrete structures will also be removed to within 1-ft
below the proposed subgrade level. In pavement areas over near-surface
miscellaneous fills, shallow groundwater, and/or loose/soft underlying
alluvial deposits, a geogrid membrane, or other chemical-improvement
techniques such as cement-admixing, will be necessary to achieve stable
pavement subgrades at the site.

#### Foundations

General

In general, the site is covered by miscellaneous fill underlain by
either Talbot Formation loose sands or compressible Talbot Formation
clays. These deposits are underlain by relatively dense sands of the
Patapsco Formation (see Appendix J for the Report on Subsurface
Exploration and Foundation Design, including a Site-Specific Design
Response Spectra and Assessment of Liquefaction Potential).

Based on this analysis, the LNG Storage Tanks, ancillary structures
(including structural steel buildings, pipe rack structures, and power
generation equipment), the LNG Spill Containment Sump, and Bulkhead
Structure will be supported on driven steel H-piles bearing in the
Patapsco Formation.

All existing structures within the footprints of proposed structures
will be demolished to expose the existing pile foundation systems. The
tops of the existing piles will be surveyed and that survey will be
overlaid on to the proposed pile driving plan to resolve potential
conflicts prior to pile driving.

If delivery of piles to the site is by land, then pile driving at the
site will commence along the southern and western site limits, working
toward the north and east, so as to maintain routes of access and
egress. If delivery of piles to the site is by barge, then the pile
driving activity will commence at the northeast corner and proceed in a
clock-wise manner around the site. Land-based staging and storage areas
for pile driving will be located in the northwestern portion of the
site.

Deep foundation construction procedures will be based on a pile driving
plan to be developed as terminal design progresses. It will include a
plan for pile load testing, determination of final driving methods based
on load-test results, and inspection of final pile locations, plumbness,
elevations and data recorded during driving to confirm installation
within specification.

LNG Storage Tanks

The proposed tanks will have an outer wall of pre-stressed concrete and
a pile supported base (e.g., structural slab) of reinforced concrete.
The base of the tank will be a minimum 2 ft-8 in thick. All tank base
features will be supported on the H-pile deep foundation system. Driven
piles shall be designed to support the design loads as end-bearing and
be driven into the competent very dense sands of the Patapsco Formation
-- these sands lie approximately 50-ft to approximately 120-ft below
existing grade. The piles supporting the LNG storage tanks will be
subject to drag forces (negative skin friction) imposed by the
settlement of the compressible Talbot Formation soils, and, to a lesser
extent, the miscellaneous fill and constructed fill soils. The pile
system and associated foundation and tank base features design will
account for these factors.

Construction of the two LNG Storage Tanks along the riverside of the LNG
Terminal will be staged to avoid interference with construction of the
Bulkhead Structure.

Ancillary Structures

Ancillary structures at the project site include structural steel
buildings, pipe rack structures, power generation equipment and other
miscellaneous ancillary structures. These structures will be supported
on steel H-Piles.

For lightly-loaded ancillary structures (such as small buildings or
other small appurtenance equipment), these structures will be supported
on individual column footings bearing on a minimum of 2 ft of structural
fill, placed and compacted consistent with the recommendations in the
appended geotechnical report (Appendix J.)

Construction of ancillary structures will be staged to avoid
interference with construction of the LNG Storage Tanks.

LNG Spill Containment Sump

The proposed Spill Containment Sump will have dimensions of 70 ft by 70
ft in plan view and 18 ft in depth. The Spill Containment Sump will be
constructed of reinforced concrete. The sump will also be supported on a
deep foundation system. Steel H-piles will be driven into the competent
sands of the Patapsco Formation to support the sump. Pile design and
installation will follow the pile driving plan procedures summarized
above. Groundwater levels, which as previously noted are detailed in the
appended geotechnical report, are present above the anticipated bottom
of the sump/basin; hence the structure design will accommodate the
existing hydrostatic conditions.

Bulkhead Structure

The near-shore bulkhead wall system will consist of a combination wall
system with intermittent structural steel king piles (stiff HZ sections)
and sheet pile (AZ sections). The king piles will be driven to bear in
the competent sands of the Patapsco Formation. The combination wall
system will be anchored via steel rod tiebacks anchored on an A-frame
pile system and/or deadman. The finished height of the wall will be
approximately 6 ft high to minimize overtopping and to reduce the
potential for flooding of the site during the design storm.

Additional explorations will be conducted within the proposed footprint
of the bulkhead structure to determine more detailed bearing elevations
in the competent sands of the Patapsco Formation once final design and
bulkhead configuration is determined.

#### Roads

During construction operations, AES plans to use the existing roadway
infrastructure within the terminal. As required, roadways will be
improved or temporary roadways will be installed for heavy construction
equipment. Temporary roadways, where necessary, will typically be of
gravel construction. The LNG Terminal operational roadways will be
installed following completion of heavy construction, as road work is
typically the last item to be completed. This work will be scheduled
after the heavy equipment (cranes, heavy haul trucks, etc.) have
completed their work so as to minimize damage to the roadways by heavy
equipment. The roadway system will be designed to provide the maximum
amount of site access and minimum traffic for deliveries of supplies and
equipment. As shown on Figure 06903-DG-000-001-01 included in Appendix
U.1, AES has designed the final roadway system to include parking lots
in the vicinity of the main process areas and a roadway system that
extends over the containment flood wall to allow access points at each
LNG Tank location. The roads will be graded to maintain the integrity of
the flood wall post construction.

#### Equipment Layout Considerations

The following considerations have been made with respect to the layout
of equipment and systems at the LNG Terminal:

-   Section 2.2 and also Section 3.4 of NFPA 59A (2001 edition) have
    been considered with respect to the siting of process equipment.

-   Equipment and buildings have been located to provide adequate access
    for normal operation and maintenance activities.

-   In accordance with the requirements of Section 3.1 and 3.2 of NFPA
    59A (2001 edition), process equipment will be located (i) outdoors
    for ease of operation, to facilitate manual fire fighting and to
    facilitate dispersal of accidentally released liquids and gases,
    and (ii) indoors, in enclosing structures that comply with the
    requirements of Sections 2.3.2 and 2.3.3 of NFPA 59A (2001 edition).

-   In accordance with the requirements of Section 3.2.2 of NFPA 59A
    (2001 edition), valves will be installed so that pumps and
    compressors can be isolated for maintenance.

-   LNG vaporizers will be installed to comply with the requirements of
    Section 5.3 of NFPA 59A (2001 edition).

#### Walls

Natural hazards associated with storm events include those arising from
storm waves/surges, high winds and torrential rainfall. For protection
against wave run-up and over topping, shore protection features will be
constructed to protect the proposed LNG Terminal footprint.

Shore protection structures will be designed to withstand the impacts
from a 100-year storm. Based on design evaluations, shore protection
features will be incorporated to further stabilize the LNG Terminal and
associated marine berths, including all operational features. These
protective features will include a six-foot bulkhead along the waters
edge in the process and LNG storage tank areas, and an eight-foot high
floodwall surrounding the LNG tanks and associated process area, to
protect the process equipment from storm surges, overtopping and
flooding.

### Drawings

#### Site Plans

Site plan 06903-DG-000-002 included in Appendix U.1 shows the location
of the terminal relative to neighboring properties.

The LNG Terminal plot plan overview (06903-DG-000-001-01), also provided
in Appendix U.1) shows the following information:

-   Identification and general arrangement of the equipment, systems and
    buildings that will comprise the LNG Terminal.

-   Arrangement of roads.

-   Arrangement of major pipe-racks.

-   Location of the LNG spill containment sump.

Additional sheets for the plot plan are also provided at a scale of
1:1200 (1-inch to 100 feet on 11-inch by 17-inch format) to show detail
that is necessary to demonstrate the safe spacing of all equipment and
buildings as required by NFPA 59A (2001 edition). These additional
sheets, numbered 06903-DG-000-001-02 through -04, are also listed in
Appendix U.1 and are listed below.

In addition, Figure 06903-DG-000-211 included in Appendix U.1 shows the
overall layout of site access and emergency routing.

#### Plot Plans

[]{#__RefHeading___Toc156025306 .anchor}Table 13.3.2.2 Plot Plans and
Site Plan

  --------------------------- -------------------------------------------
  Drawing Number              Description

  06903-DG-000-001-01         Facility Plot Plan -- Overview

  06903-DG-000-001-02         Facility Plot Plan -- Pier

  06903-DG-000-001-03         Facility Plot Plan -- Tank Area

  06903-DG-000-001-04         Facility Plot Plan -- Process Area

  06903-DG-000-002            Site Plan

  06903-DG-000-021            Site Access and Emergency Routing
  --------------------------- -------------------------------------------

## Basis of Design

The LNG Terminal is designed in accordance with the requirements of 49
CFR Part 193, 33 CFR Part 127 and NFPA 59A (2001 edition, which USDOT
incorporated within 49 CFR Part 193 on April 9, 2004; although, where
more stringent, the design meets the requirements of NFPA 59A 2006
edition). Appendix F provides a summary of compliance with these
requirements. Compliance with Additional codes and standards that apply
to the design of the LNG Terminal are included in Appendix D.

This section describes the basis for the design of the LNG Terminal. The
following reference documents are also appropriate to this design basis.

-   General Arrangement Plot Plan, 06903-DG-000-001 (Appendix U.1).

-   Process Flow Diagram, 06903-PF-000-001 (Appendix U.5).

-   Heat and Mass Balance Diagrams, 06903-PF-000-011 (Appendix U.5).

-   Design Codes and Standards, 06903-TS-000-022 (Appendix D).

-   Engineering Development Standard, 06903-TS-000-001 (Appendix C).

### Guarantee Conditions 

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Site Conditions

#### Site Elevations

The existing site elevation varies from 7 to 13 ft relative to NAVD88.
The site will be graded and partially filled as needed to facilitate
construction and storm water management. Site elevations will be
determined during final design. The table below lists estimated
elevations as of this filing.

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

#### Elevation Reference (NAVD) 

The zero elevation reference datum for the LNG Terminal is the North
American Vertical Datum of 1988 (NAVD 88). The Mean Lower Low Water
(MLLW) level for the Terminal Site is -0.61 ft NAVD88, based on the
nearest National Oceanic and Atmospheric Association (NOAA) Tidal
Benchmark Station. For Sparrows Point, the nearest station is Station
#8574680 located at Baltimore Harbor at latitude 39° 16.0\' N and
longitude 76° 34.7\' W.

#### Channel Depth

The depth of the navigation channels from the Brewerton Angle to the
berth varies from a minimum of 15 feet up to a maximum depth of 40 feet.
The channels require dredging.

#### Channel Width

The width of the existing navigation channels, known as the "Marine
Channel," is about 250 ft with a dredged depth of about 30 ft (MLLW).

#### Berth Depth

The LNG ships will be selected and operated such that their maximum
arrival draft will not exceed 40.5 ft. The berth will be sited where the
water depth is at least 45 ft at Mean Lower Low Water (MLLW) to provide
adequate under keel clearance at all tide stages.

#### Tidal Range, Elevations

[]{#__RefHeading___Toc156025307 .anchor}Table 13.4.2.6 Site Tidal
Elevations

  ------------------------------------------------------------------------
                                     Tidal Plane To MLLW (ft)  To NGVD\
                                                               29 (ft)
  ---------------------------------- ----------- ------------- -----------
  Highest Observed Water Level       HOWL        7.697         7.648

  Mean Higher High Water             MHHW        1.660         1.611

  Mean High Water                    MHW         1.362         1.313

  North American Vertical Datum of   NAVD 88     0.833         0.784
  1988                                                         

  Mean Sea Level                     MSL         0.801         0.752

  Mean Tide Level                    MTL         0.791         0.742

  National Geodetic Vertical Datum   NGVD 29     0.049         0.00
  of 1929                                                      

  Mean Low Water                     MLW         0.220         0.171

  Mean Lower Low Water               MLLW        0.000         -0.049

  Lowest Observed Water Level        LOWL        -5.105        -5.154
  ------------------------------------------------------------------------

####  {#section-2 .unnumbered}

#### Normal Channel Current

Currents in the approach channel are expected to be quite low. According
to preliminary hydrodynamic modeling results the tidal currents in the
channel are expected to range from 0 to 0.5 knots.

Discussions with members of Baltimore Pilot's Associations have
confirmed the findings of the preliminary hydrodynamic modeling.

#### Frost Line Depth

The frost line depth at the site is 36\" below ground surface.

### Emissions  {#emissions .Style-Heading-3-+-Arial-10-pt}

Air emissions will result from the operation of the Hot Water Heaters
B-411, Diesel Fire Water Pump P‑603, Seawater Fire Pumps P-605,
Discretionary Vent Heater B-209 and Emergency Diesel Generator G‑502.
Emissions from these sources are summarized in Resource Report 9, *Air
and Noise Quality*.

### Seismic

A site-specific seismic evaluation for the LNG Terminal has been
completed. The approach has been developed to meet the requirements
presented in the National Fire Protection Association (NFPA) 59A (2006
edition) for LNG facilities, and the requirements of the FERC for
seismic evaluation for LNG terminals (18CFR380.12(o)).

The overall seismicity of the region is considered to be relatively low.
The Terminal Site is located in a seismic region that has generated
small earthquakes and has experienced ground shaking from larger more
distant earthquakes.

The site-specific seismic evaluation was performed in order to develop
site-specific design response spectra for the Safe Shutdown Earthquake
(SSE), having a probability of 2 percent in 50 years (the 2475-year
event), and the Operating Basis Earthquake (OBE), having a probability
of 10 percent in 50 years (the 475-year event). Due to the variability
of the soil profile in the region of Tanks 201A/B and Tanks 201C/D,
separate design spectra sets were developed for these two areas of the
Terminal Site. Separate horizontal- and vertical-component design
spectra for SSE and OBE earthquake events at 1, 2 and 5 percent damping
were developed. The geotechnical report in Appendix J contains the
site-specific evaluation study and includes the site-specific design
spectra.

Although the assessment of the majority of on-site sands indicates
non-liquefiable conditions during the SSE, a few data points suggest
that there is a very loose layer of sand with very little fines (silts
and clay particles passing the No. 200 U.S. sieve) at a depth ranging
from approximately 15 to 30 ft. below ground surface (bgs) and within
the footprint of three of the four proposed tanks. This very loose,
clean sand may liquefy during the 2475-year SSE earthquake event
resulting in liquefaction-induced increases in pore-water pressure with
loss of soil shear strength and some ground settlement. To confirm the
presence of this loose sand layer and to obtain further Standard
Penetration Test (SPT) data for more definitive evaluation of
liquefaction potential, additional boreholes will be advanced during
final design within the region of the proposed tank locations as a
minimum.

As discussed above, the tanks and other settlement-sensitive structures
at the Terminal Site should be supported on pile foundations bearing in
the underlying competent sands of the Patapsco Formation. Hence, the
liquefaction-induced effects of potential reduced soil shear strength
and downdrag forces that would be induced on the pile foundations will
be incorporated in the design of the foundations. This will ensure that
the piles safely carry the combined static and dynamic loads. Appendix J
contains the detailed assessment of liquefaction potential.

### Climatic Conditions

Climate conditions were determined for the Sparrow Point site by review
of National Climatic Data Center meteorological records for
Baltimore-Washington International (BWI) Airport for the 45-year time
period from 1961 through 2005. This location is approximately 10 miles
west-southwest of Sparrows Point, and is considered representative of
the site conditions. These records include hourly measurements of
temperature, humidity and wind speed.

#### Minimum design temperature

The minimum ambient temperature used in the design of Sparrows Point was
-7°F, based on review of climate data.

The design temperature used for thermal exclusion zone calculations was
26°F. This value was determined by reviewing climate data from
1961-2005.

#### Maximum design temperature 

The maximum ambient temperature used in the design of Sparrows Point was
104°F, based on review of climate data.

The design temperature used for heat and mass balance calculations for
heat leak into cryogenic piping and equipment was 95°F. The design
temperature used for sump walls for vapor dispersion calculations was
70°F.

#### Barometric Pressure

The average barometric pressure over the period from 1974-2005 was 1014
mbar.

#### Wind Direction

In general the wind direction is variable with a slight predominance of
wind from the west-northwest. The site design assumed complete
variability in wind direction.

#### Design wind speed

For the LNG storage tanks, the design wind velocity is 150 mph per the
requirements of 49 CFR 193.2067. For other process equipment containing
LNG, the design wind velocity per 49 CFR 193.2067 is obtained from
ASCE-7 and is 90 mph for the Terminal Site. Similarly, the design wind
velocity for site buildings is 90 mph.

The design wind speed used for thermal radiation exclusion zone
calculations ranged from 0 to 18 mph. The wind speed assumed in the
vapor dispersion calculations was 4.5 mph. These values were determined
by reviewing climate data from 1961-2005.

The design wind speed used in heat and mass balance calculations for
heat leak into cryogenic piping and equipment was 10 mph.

#### Hurricane Design Force

Based on a review of the NOAA National Climatic Data Center for the
period of 1974 to December 2006, three hurricanes and five tropical
storms have occurred in Maryland. The maximum sustained wind speed
recorded was 50 mph with gusts ranging from 35 to 72 mph. The hurricanes
were classified as Category 1 hurricanes or tropical storms.

The design wind speeds are listed in section 13.4.5.5.

#### Storm Surge Height

Storm surge refers to the increase in water level above daily tidal
fluctuations during a storm event. This includes effects from barometric
pressure, wind stress, and dynamic wave setup. Flood elevations
associated with storm events of varying return periods were obtained
from the 2004 Flood Insurance Study by the Federal Emergency Management
Agency. The anticipated flood levels for the area adjacent to the study
area are as follows:

[]{#__RefHeading___Toc156025308 .anchor}Table Error: Reference source
not found Anticipated Flood Elevations

  -----------------------------------------------------------------------
  Event                         Elevation, ft NAVD88
  ----------------------------- -----------------------------------------
  10-year Flood                 3.4

  50-year Flood                 6.3

  100-year Flood                7.7

  500-year Flood                10.3
  -----------------------------------------------------------------------

####  {#section-3 .unnumbered}

#### Rain Fall during the 100-Year Storm

The precipitation rate for a 100-year storm is 3.08 inches/hour. This
information is obtained from the \"Precipitation-Frequency Atlas of the
United States\" NOAA Atlas 14, Volume 2, Version 2 for location: 39.2186
N 76.4964W @ 0 feet.

#### Snow Load

The annual total snow fall ranged from a low of 5 inches to a high of 60
inches over the 45-year period studied. The average annual total snow
was about 20 inches during this period.

### Shipping

#### LNG ship capacity range (expected) 125,000 m^3^ to 217,000 m^3^

#### LNG vessel unloading frequency maximum 200 per year

### Mooring

#### Number of berths 2

#### Turning basin Yes

#### Number of platforms 1

#### Trestle Yes

### LNG Cargos

#### Source See Table 13.1.3, LNG Sources

#### LNG specifications, range of conditions

The LNG Terminal is designed to receive LNG from several possible LNG
production sources. A range of compositions is used for the design
basis. A typical case is given for performing the Heat and Material
balances but equipment is rated to accommodate both light and heavy
compositions as stated in Table 13.1.3, LNG Sources.

#### Maximum cargo equilibrium pressure, psig 2.5 psig

### Unloading

#### Unloading arms and size per berth, liquid 3 x 16-inch

#### Unloading arms and size per berth, vapor 1 x 16-inch

#### Unloading maximum rate 12,500 m3/hour

#### Unloading minimum pressure at ship manifold 100 m head (approx. 65 psig)

#### Design pressure, arms and piping 150 psig (arms), 275 psig (piping)

#### Design vapor return pressure at ship manifold 1.45 psig

#### Maximum vapor return temperature at ship manifold -180°F

###  Feed Gas

Not applicable

###  Pretreatment

Not applicable

###  Regeneration Gas

Not applicable

###  Liquefaction

Not applicable

###  Fractionation Products

Not applicable

###  Storage

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### LP Pumps

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### HP Pumps

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### IP Pumps

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### HP Vaporizers

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### IP Vaporizers

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

###  Gas Liquid Removal

Not applicable

###  Btu Adjustment 

#### Process Not applicable

#### Throughput capacity Not applicable

#### Pipeline Btu and composition specification 

Gas qualification specifications are set forth in the pro forma FERC Gas
Tariff included as part of the Natural Gas Act (NGA) section 7(c)
application submitted to the Commission by Mid-Atlantic Express for its
approval. Such specifications are intended to be consistent with the
Commission\'s orders addressing gas interchangeability standards, and to
ensure that the natural gas can be safely delivered to downstream
interconnecting pipelines. AES is continuing to review the required gas
quality tariff provisions, but preliminarily the standards set forth are
intended to be consistent with the pipelines of Texas Eastern Gas
Transmission Company (Tetco), Transcontinental Pipeline Company
(Transco), and Columbia Gas Transmission Company (Columbia).

###  HP Sendout Battery limit

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### IP Fuel Gas Conditions

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Vapor Handling 

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Discretionary Vent Stack

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Flares

Not applicable

###  IP Fuel Gas System

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### LP Fuel Gas System

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### LNG Trucking

Not applicable.

###  Electrical

#### Main power utility supplier BG&E

#### Utility supply voltage 110 kV

#### Utility supply capacity Two 110kV lines, each at 200 MWe

#### Main power generated onsite No (possible future power plant)

#### Main power generators N/A

#### Emergency power supply On-site generated

#### Emergency power generators 1 Diesel Generator

#### Emergency power voltage 4.16 kV

#### Emergency power capacity 2.0 mVA

#### UPS services, voltage, size and capacity 120 V

###  Control Instrumentation

#### Design of Distributed Control System TBD in detailed design phase

#### Control System software supplier TBD in detailed design phase

#### Safety instrumented system manufacturer TBD in detailed design phase

###  Instrument Air 

#### Compressors Oil-free reciprocating compressor

#### Drying system Heatless

#### Flow rate 620 scfm

#### Operating Pressure 80-105 psig

###  Service Air

#### Compressors (Same compressors as Instrument Air)

###  Inert Gas

The only inert gas to be used at the LNG Terminal is nitrogen, which is
covered in 13.4.36.

###  Nitrogen

#### Source Cryogenic storage dewar

#### Liquid nitrogen storage capacity 8,300 gal

#### Flow rate 334 scfm design (29 scfm continuous)

#### Pressure 110 psig

###  Fire Water

#### Source On-site: T-601 Fire Water Tank; backup from Patapsco River 

#### Fire Water Pump (P-602) Centrifugal, Electric

#### Fire Water Pump (P-603) Centrifugal, Diesel

#### Jockey Pump (P-604) Centrifugal, Electric

#### Seawater Fire Pump (P-605A/B/C/D/E/F) Centrifugal, Diesel

#### Fire Water Pump rated capacity 3,000 gpm 

#### Jockey Pump rated capacity 10 gpm 

#### Deluge Pump rated capacity 4,500 gpm 

#### Make up water source Baltimore County water with river water backup

###  Cooling Water

The LNG Terminal does not require cooling water.

If installed, the Power Plant will be cooled by transferring rejected
heat from the condenser to a heat transfer fluid, which in turn
transfers this heat to the LNG in the vaporization system. At times when
the Power Plant is in operation and there is insufficient LNG sendout to
dissipate the total condenser heat rejection, the Power Plant will
reject the balance of the condenser heat to a cooling tower loop. This
cooling tower will require makeup water from the municipal source to
replace the cooling water evaporated from the tower.

###  Hydrotest Water

The LNG Tanks and piping will be hydrostatically and pneumatically
tested in compliance with the applicable codes that govern the tank and
/ or pipe design. Hydrotesting will be performed on the inner container
of each LNG storage tank. The inner containers will be made of nine
percent nickel. Hydrotest water will be taken from the Patapsco River
and will be filtered to prevent the ingress of coarse materials. The
test water will be sampled and tested for compliance with API 620,
Section Q.8.3 requirements for test water quality prior to use. If
necessary to meet API requirements, the water will be treated with
corrosion inhibitors prior to admission to the tanks.

Water will be pumped from the Patapsco River into the inner LNG tank
through the manhole in the outer containment tank roof. In accordance
with API 620, the water flow rate will not exceed three feet of depth
per hour (equivalent to 17,800 gpm for each 246-foot inner diameter
inner tank), to a depth of about 76\'-1\" above the inner tank floor.
Accordingly, the time to fill the tank will be at least 25 hours of
pumping at the maximum allowed rate. Approximately 28 million gallons of
water will be required to test each tank. The water residence time in
the tank will be sufficient to meet the testing time required per API
620 (including a one-hour hold time) and will otherwise be limited to
prevent any possible corrosion.

Due to the timing of the construction, it is unlikely that the same
water can be reused for testing of two or more of the three tanks.
Therefore, after each tank hydrotest, the test water will be pumped out
of the tank, tested, treated (if necessary) and discharged to the
Patapsco River in a location and manner in accordance with applicable
permits and regulations as described in Section 2.4.5.2 of Resource
Report 2, *Water Use and Quality*.

###  Utility (Service) Water

#### Source Baltimore County municipal water system

#### Flow Rate 60 gpm

#### Pressure 90 psig 

###  Fire Protection

#### Fire Protection Service 

AES is working to develop an Emergency Response Plan that will describe
the coordination with external stakeholders, including fire protection
service providers. See Section 13.15 and Resource Report 11 for
additional information.

###  Site Security

AES will employ a Facility Security Plan developed to meet the
requirements of the USCG, Department of Homeland Security, Maritime
Security (Facility) regulations, 33 CFR 105. The purpose of the Plan is
to provide procedures that will enhance the safety and security of the
LNG Terminal against unlawful acts. The Facility Security Plan, which
has been submitted to the USCG, contains sensitive security information
(SSI) and for that reason has not been included in this Resource Report
13.

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

The site will be surrounded with a security fence with limited access
openings. The fence will extend to the pier to limit access to LNG
Terminal personnel.

The LNG Terminal will be adequately lit to provide an average of 5
foot-candles of lighting at each berth, 5 foot-candles at each active
access point, and an average of 1 foot-candle throughout the remainder
of the facility. A minimum of ½ foot-candle shall be provided throughout
the facility. Lighting along the waterside of the LNG Terminal and on
the pier will be located or shielded so as not to mislead or otherwise
interfere with navigation on the adjacent waterways.

\[Redacted - Volume V-A, CEII, contains the full text version of this
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## Major Process Systems

### Marine

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Unloading

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Feed Gas

Not applicable

### Liquefaction

Not applicable

### Fractionation

Not applicable

### Vapor Handling

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### LNG Sendout System

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Gas Liquid Removal

Not applicable

### Btu Adjustment 

Not applicable

###  Vent and Flare Systems

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Pressure Relief

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Sendout Metering 

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### LNG Product Loading - Marine

Not applicable

###  LNG Product Loading/Unloading - Trucking

Not applicable

###  Commissioning Plan

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

## LNG Storage Tanks

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### General

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Tank Foundation

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Outer Containment

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Report\]

### Inner Containment

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Seismic Loads on Inner and Outer Tanks

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Report\]

### Wind Loads on Outer Tank

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Report\]

### Insulation System

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Tank Instrumentation

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Fittings, Accessories, and Tank Piping

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Stairways and Platforms

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Report\]

### Cryogenic Spill Protection

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Anchorage

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Painting

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Tank Lighting and Convenience Receptacles

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Report\]

###  Electrical Grounding

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

###  Welding

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Report\]

###  Testing and Inspection

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Report\]

###  Procedures for Monitoring and Remediating Stratification

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

###  Tank Secondary Bottom and Corner Protection

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Drawings

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

## Utilities

### Instrument Air

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Service Air

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Nitrogen

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Potable Water

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Service Water

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Storm Water

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Wastewater

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

## Equipment Data

### Equipment List with Design Conditions

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Equipment Data

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

## Instrumentation

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Description of Control System

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Plant Control and Monitoring System Components 

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Field Control Instruments

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Control Communication and Control Power  {#control-communication-and-control-power .Style-Heading-3-+-Arial-10-pt}

\[Redacted - Volume V-A, CEII, contains the full text version of this
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### Backup Power Supply

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Sample Conditioning, Analyzers and Custody Transfer

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### Drawings {#drawings-3 .Style-Heading-3-+-Arial-10-pt}

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## Safety Instrumentation System

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### Description of the SIS 

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### SIS Components

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Report\]

### Communication and Control Power

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Backup Power Supply

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Report\]

### Emergency Shut Down (ESD)

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Drawings and Tables

\[Redacted - Volume V-A, CEII, contains the full text version of this
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## Electrical

###  Description of Electrical System

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Hazardous Area Classification Basis

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Report\]

### Electrical Tables and Lists

\[Redacted - Volume V-A, CEII, contains the full text version of this
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### Electrical Drawings

\[Redacted - Volume V-A, CEII, contains the full text version of this
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## Fuel Gas

### Description of Fuel Gas System

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Drawings

## Spill Containment Systems

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

###  Description of Spill Containment Systems

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Thermal Radiation Exclusion Zones

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

###  Flammable Vapor Exclusion Zones

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

## Hazard Detection Systems

###  Description of Hazard Detection Systems

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### Description of Hazard Warning Systems Including Offsite, Plant Wide and Local Area

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### Hazard Detector List

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### Drawings

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## Fire Suppression and Response Plan

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Report\]

### ERP Development 

\[Redacted - Volume V-A, CEII, contains the full text version of this
Report\]

### ERP Schedule

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## Hazard Control Systems

###  Description of Hazard Control Equipment and Systems

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###  Dry Chemical Basis of Design

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### Matrix of Hazard Control Equipment

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###  Dry Chemical System Drawings

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## Fire Water

###  Description of Fire Water System

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### Matrix of all Fire Water Delivery Equipment

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### Fire Water Drawings

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## High Expansion Foam System 

###  Description of Foam System and Equipment

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### Foam System Basis of Design

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### Matrix with Tag Number, Location, Type/Model of Foam Equipment.

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###  Drawings

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## Security

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### Security Description

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### Site Access Control

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### Cameras

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### Intrusion Detection

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## Piping

###  Piping Systems

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### Piping Specification

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### Piping Insulation, Cold

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###  Piping Insulation, Hot

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### Pipe Racks

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### Piping Specification Tabular Summary

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### Piping Insulation Tabular Summary

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### Pipe Rack and Piping Arrangement Drawings

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## Foundations and Supports

###  Description of Foundations and Supports

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### Drawings

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## Buildings and Structures

###  Description of Buildings

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### List of Buildings with Dimensions

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### Drawings

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## Process Drawings

###  Process Flow Diagrams and Material and Energy Balances

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## Piping and Instrument Diagrams

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### Drawing List with Revision Number and Issue Date

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###  Piping and Instrumentation Legend and Symbols

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