LNG Permit To Construct

APPLICATION TO
NOVA SCOTIA UTILITIES AND REVIEW

BOARD
APPLICATION TO
PERMIT TO CONSTRUCT
NOVA SCOTIA UTILITIES AND REVIEW BOA
FOR A
PERMIT TO CONSTRUCT
Table of Contents
1 INTRODUCTION ........................................................................................................................ 1
1.1 THE PROPONENT .................................................................................................................. 1
1.2 THE PROJECT ........................................................................................................................ 1
1.3 FRONT END ENGINEERING DESIGN (“FEED”) ................................................................... 2
1.4 BENEFITS TO NOVA SCOTIANS ........................................................................................... 2
2 GAS PLANT FACILITY REGULATIONS AND THE CODE OF PRACTICE ............................. 3

2.1 APPLICATION FOR A PERMIT TO CONSTRUCT ................................................................. 3
3 PROCESS SAFETY MANAGEMENT ........................................................................................ 3

3.1.1 TECHNOLOGY INFORMATION FOR PROCESS, UTILITY AND SUPPORT SYSTEMS .... 4
3.1.2 PROCESS INFORMATION FOR PROCESS, UTILITY AND SUPPORT SYSTEMS .......... 20
3.2 PROCESS HAZARD ANALYSIS .......................................................................................... 21
3.2.1 HAZOP ................................................................................................................................ 22
3.2.2 MANAGEMENT OF CHANGE ............................................................................................ 23
3.2.3 PRE-START UP SAFETY REVIEW .................................................................................... 25
3.2.4 OPERATING PROCEDURES (CSA Z276-01 CLAUSE 12) ................................................ 25
3.2.5 TRAINING (CSA Z 276-01 CLAUSE 3.4 AND 12.5) ............................................................ 26
3.2.6 MECHANICAL INTEGRITY (CSA Z276-01 CLAUSE 12.4 AND 12.5) ................................ 26
3.2.7 INCIDENT INVESTIGATION .............................................................................................. 27
3.2.8 EMERGENCY PLANNING & RESPONSE (CSA Z276-11 CLAUSE 13.3.3) ....................... 27
3.2.9 AUDITING (GAS PLANT FACILITY REGULATIONS SECTION 20) ................................... 27
4 FEED ........................................................................................................................................ 28
4.1 CHEMICAL HAZARD INFORMATION .................................................................................. 30
4.2 PROCESS CHEMISTRY AND SYSTEMS ............................................................................. 31
4.3 PLOT PLANS FOR SITING AND LAYOUT ........................................................................... 31
4.4 PLOT PLAN FOR LAYOUT OF FIRE PROTECTION SYSTEM ............................................ 31
4.5 PLOT PLAN FOR LAYOUT OF DETECTION, CONTROL AND INTERLOCK SYSTEMS ... 32
4.6 PLOT PLAN OF SPILL CONTAINMENT AND DRAINAGE .................................................. 32
4.7 PLOT PLAN OF AREA ELECTRICAL CLASSIFICATION ................................................... 32
4.8 BLOCK FLOW DIAGRAM OF ISOLSATION AND SHUTDOWN SYSTEMS ....................... 32
4.9 PROCESS FLOW DIAGRAMS .............................................................................................. 32
4.10 PIPING AND INSTRUMENT DIAGRAMS (PID) .................................................................. 32
4.10.1 EQUIPMENT ..................................................................................................................... 32
4.10.2 PIPING .............................................................................................................................. 32
4.10.3 BUILDINGS ....................................................................................................................... 32
4.11 APPLICABLE CODES AND STANDARDS ........................................................................ 34
4.12 RELIEF SYSTEM AND SIZING BASIS ............................................................................... 34
4.13 VENTILATION SYSTEM DESIGN AND SIZING BASIS...................................................... 34
4.14 BASIC PROCESS CONTROL SYSTEM ............................................................................. 34
4.15 SAFETY INSTRUMENTED SYSTEMS ............................................................................... 34
4.16 INTERLOCK CAUSE AND EFFECT CHART ...................................................................... 34
4.17 DESIGN AND SAFETY STUDIES ....................................................................................... 34
4.18 ELECTRICAL POWER SYSTEMS ...................................................................................... 34
4.19 COMPLIANCE WITH REGULATIONS ................................................................................ 35
5 CLIMATOLOGY AND SITE STUDY ........................................................................................ 35
5.1 SITE STUDY .......................................................................................................................... 35
5.2 CLIMATOLOGY STUDY ....................................................................................................... 35
6 SEISMIC REVIEW .................................................................................................................... 35
7 PRELIMINARY HAZARD AND OPERABILITY STUDY (HAZOP) .......................................... 37
8 FACILITY SITING AND LAYOUT ANALYSIS ......................................................................... 37
9 PRELIMINARY FACILITY AND SECURITY ASSESSMENT .................................................. 39
10 ANNEXES ................................................................................................................................. 41
10.1 ANNEX P – PUBLIC DOCUMENTS .................................................................................... 42
10.2 ANNEX 1 – PROJECT MANAGEMENT - CONFIDENTIAL AND PROPRIETARY ............. 43
10.4 ANNEX 2 – PROCESS - CONFIDENTIAL AND PROPRIETARY ....................................... 44
10.5 ANNEX 3 – PIPING & LAYOUT - CONFIDENTIAL AND PROPRIETARY .......................... 57
10.6 ANNEX 4 – CIVIL STRUCTURAL & CONSTRUCTION - CONFIDENTIAL AND
PROPRIETARY .............................................................................................................................. 58
10.7 ANNEX 5 – MARINE -CONFIDENTIAL AND PROPRIETARY............................................ 59
10.8 ANNEX 6 – MECHANICAL, HVAC & TANKS - CONFIDENTIAL AND PROPRIETARY .... 60
10.9 ANNEX 7 – ELECTRICAL - CONFIDENTIAL AND PROPRIETARY .................................. 61
10.10 ANNEX 8 – INSTRUMENTS & TELECOMS - CONFIDENTIAL AND PROPRIETARY ..... 63
10.11 ANNEX 9 – SAFETY & ENVIRONMENTAL CONFIDENTIAL AND PROPRIETARY ....... 65
10.12 ANNEX 10 – COMMISSIONING - CONFIDENTIAL AND PROPRIETARY ....................... 69
10.13 ANNEX 11 – WATER SUPPLY PIPELINE - CONFIDENTIAL AND PROPRIETARY ....... 70
Goldboro LNG: Application for a Permit to Construct 2

1 INTRODUCTION
1.1 THE PROPONENT
Pieridae Energy (Canada) Ltd., for itself and as general partner of Goldboro LNG Limited
Partnership, (collectively, Pieridae) is proposing to develop and operate the Goldboro LNG
Project, as described below, (the Project or the Facility) located in Goldboro, Guysborough
County, Nova Scotia (NS). Pieridae is controlled by Pieridae Energy Limited, a Canadian
public corporation which is focused on the development of fully integrated energy
activities, from upstream production to the sale of liquified natural gas (LNG).
1.2 THE PROJECT

The Project includes a natural gas liquefaction plant, liquefied natural gas tanker terminal,
a power plant, a marine jetty for loading and other associated marine facilities. The Project
is anticipated to produce approximately ten million tonnes of LNG per annum and have
onsite storage capacity of 380,000 cubic metres of LNG. The Project is located adjacent to
the Maritimes & Northeast Pipeline (M&NP), a 1,400 kilometre transmission pipeline
system built to transport natural gas between developments in Nova Scotia, New
Brunswick and the northeastern United States.
The following is a 3D rendering of the Facility.

1.3 FRONT END ENGINEERING DESIGN (“FEED”)
A detailed FEED was performed by Pieridae using the services of Chicago Bridge & Iron
(“CB&I”), Golder Associates and Dillon Consulting, amongst others, to create a full plant
specification that could be used as the basis of permitting for the Project, and to form the
basis of the technical specification for its construction.
This involved the gathering of data on the physical characteristics of the site as well as
metrological and meteocean conditions pertaining to the site and seaways. The FEED was
performed applying the current codes and regulations in relation to the site’s location, and
those of the industry, and executed using good engineering practice and internationally
applied systems. This included safety analysis of the initial design using international
engineering practices (HAZID/HAZOP/SIL) and international and industry standards
relating to the marine activities. A more detailed overview of the FEED is contained in
Section 4 of this application.
FEED documents and information generated during, or as a result of the FEED, unless
otherwise contained in the body of this document, remain proprietary and confidential and
are not available to the public.
1.4 BENEFITS TO NOVA SCOTIANS

Pieridae maintains its objective of maximising the economic benefits for the local, regional
and indigenous communities. Early in the Project’s development, Pieridae engaged with
local economic development agencies, the community (through Open House events and
the establishment of the Community Liaison Committee), Fisheries (through the Fisheries
Liaison Committee) and First Nations groups, to identify opportunities and businesses that
could provide labour, goods and services to the Project in order to maximise the Nova
Scotia content, as well as working with local educational institutions to identify local
training opportunities.
Further, a special needs collective agreement was ratified on 3 May, 2017 between the
Nova Scotia Construction Labour Relations Association (as Pieridae’s agent) and each of
the fifteen unions involved in providing the workforce to the Project during its construction.
Together with existing collective agreements, this agreement provides the terms of
engagement with local tradespersons together with the training and employment
opportunities for qualified First Nations members, women and local residents. Pieridae
also has in place a communication plan with Nova Scotian Mi'kmaq First Nations.
As required by Clause 9(2)(e) to (f) of the Gas Plant Facilities Regulations, Pieridae, and
its third party contractors, are committed to providing employment, training and contracting
opportunities firstly to Nova Scotians, where their skills, qualifications and businesses
satisfy the employment and contracting requirements.

2 GAS PLANT FACILITY REGULATIONS AND THE CODE OF
PRACTICE
2.1 APPLICATION FOR A PERMIT TO CONSTRUCT
Pieridae obtained its Class II Environmental Assessment Approval from the Minister of
Environment on March 21, 2014 and can be found on the Goldboro LNG website, or by
following this link, https://www.novascotia.ca/nse/ea/goldboro-lng.asp
Pieridae has advanced the commercial, environmental and financial aspects of the
Project. It will imminently conclude, amongst other matters, an engineering, procurement
construction and commissioning (“EPCC”) contract with its EPCC Contractor of choice,
appoint its lead Financial Advisor, and is continuing in its efforts to satisfy all
Environmental Assessment conditions. Pieridae is poised to take its final investment
decision this year and, as such, wishes to apply for its Permit to Construct.
3 PROCESS SAFETY MANAGEMENT
The Safety and Environmental Engineering (“SEE”) objectives of the Project are to design,
construct and operate a facility without harm to construction or operations personnel or to
the general public and to minimize the impact of this facility on the environment. The
Project’s current SEE Philosophy can be found in Annex 9 Document No. 188479-000-SE-
PH-00001.
As the design of the facility is developed further through the detailed engineering phase, a
number of companion documents will be generated detailing safety and environmental
protection measures required to realise the SEE Philosophy. Each individual plan will be
based on the standards and philosophies set forth in the above philosophy, and will be
audited and controlled to ensure all third parties achieve the best possible results in terms
of keeping the environmental impact of the Project to a minimum and that a “zero harm”
philosophy for safety issues is applied.
A key aspect of this philosophy is the full integration of safety and environmental
considerations (including working environment and human factors) into all aspects of the
design, including materials, process and equipment selection, and site and layout choices.
This document defines the overall safety philosophy for the project, and identifies the
relevant documents for reference on specific aspects of the project.
The document is structured around four key areas of SEE Management:
1. Design Safety
2. Working Environment (Occupational Health)
3. Human Factors
4. Environmental Protection.
The main SEE documents that form the basis of the SEE design and are required for the
FEED project are set out below in the following table:

Document Scope Annex
Design SEE Philosophy Over-arching safety philosophy for the Annex 9 Document
project. Identifies companion No. 188479-000-
documents for reference on specific SE-PH-00001 Rev
aspects of project. C
Environmental Design Basis Describes how emissions from the Annex 9 Document
facilities to the environment are No. 188479-000-
controlled and managed to comply with SE-DB-00003
regulatory requirements.
Fire & Gas, Spill Detection Basis of Sets out the requirements for the fire Annex 9 Document
Design and gas detection systems. No. 188479-000-
SE-DB-00001
Fire Protection Basis of Design Details the requirements for active and Annex 9 Document
passive fire protection. Nos. 188479-000-
SE-DB-00004,
188479-000-SE-
04-079001 and
188479-000-SE-
079002
LNG Spill Containment / Impoundment Details the requirements for LNG spill Annex 9 Document
Basis of Design containment and impoundment. No. 188479-000-
SE-DB-00002
The Project will be managed in line with the HSE Management System detailed within the
project Safety Management Plan, see Annex 9 Document No. GPL-PEL-HSE-PRO-0001-
PROCESS SAFETY INFORMATION
3.1.1 TECHNOLOGY INFORMATION FOR PROCESS, UTILITY AND SUPPORT

SYSTEMS
3.1.1.1 PROCESS CHEMISTRY
The Facility is an onshore gas processing plant, a marine terminal for the loading of LNG
onto LNG carriers, a wharf for mooring associated support vessels and unloading
materials during construction. The key components of the Facility are listed below and
discussed in more detail in this section.
Component Description
Liquefaction Plant • Two liquefaction trains, each with a nominal capacity of 4.8
MTPA of LNG
• Each train converts natural gas from the M&NP system to
LNG at atmospheric pressure and approximately -162
Degrees Celsius for export to overseas markets
LNG Storage Tanks • Two full containment cryogenic tanks each with a net
capacity of 190,000m3
• Allowance designed in for a third full containment tank

Marine Facilities • A jetty trestle for the LNG transfer lines, loading arms access
road and two LNG carrier loading berths;
• A Marine Offloading Wharf for the unloading of construction
equipment and latter, for the mooring of the tug and pilot
vessels
Power Generation • On site gas turbine power generation to support the Facility
• Emergency diesel generators as backup
Feed Gas Pipeline and Inlet • M&NP will construct a feed gas supply pipeline to the Facility
Facilities including pigging, metering and compression to meet intake
compression requirements of the Facility
Potable Water Pipeline and Intake • Supply pipeline from Meadow Lake to the Facility to supply
Structure raw water
• Onsite treatment facilities
Buildings and Utilities • Multiple administrative, control and maintenance buildings
• Utilities to support the Facility
Temporary Work Camp • For the duration of the construction phase, the Project will
include a work camp situated to the northern site boundary
Information Centre • Pieridae plans to operate an information centre at the site

from the start of construction
This section should be read in conjunction with the Overall Block Flow Diagram in Annex P
Document No. 188479-000-PE-RP-00002 and Overall Process Flow Scheme in Annex 2
Document 1884779-000-PR-SK-000001.
Inlet Facilities
Gas feeding the Facility will be received via the Maritimes and Northeast Pipeline (M&NP)
connection from the existing gas plant to the inlet of the Facility. The new feed gas pipeline
will be constructed by M&NP and is proposed to have a fiscal quality metering station
outside of the Facility.
The pipeline gas is heated if required by hot oil to achieve the correct temperature at the
inlet of the Acid Gas Removal Unit and to protect against hydrate formation. The pressure
of the heated pipeline gas is controlled to meet the required pressure for the downstream
units. The pressure-reduced gas passes through an Inlet Gas KO Drum to remove any
free liquids or particulates. This unit is common to both LNG Trains.
Mercury Removal Unit
The mercury removal unit removes any mercury present in the feed gas to prevent
mercury amalgam corrosion or liquid metal embrittlement of aluminium equipment in the
cryogenic sections of the plant. Removal of trace mercury early in the liquefaction process
has an additional benefit of reducing release of mercury to atmosphere and reducing the
health risk to operations personnel. A non-regenerable sulphur impregnated activated
carbon adsorbent (or similar) is used to remove any trace quantities of mercury. This unit
is common to both LNG Trains.

Acid Gas Removal
The Acid Gas Removal Unit (AGRU) removes acid gas components from the feed gas in
order to meet LNG specifications and prevent freezing in the cryogenic sections of the
plant. The acid gas components are predominantly carbon dioxide (CO2) with trace
quantities of Hydrogen Sulphide (H2S) and other sulphur species. The AGRU will utilise
the BASF OASE® Purple formulated amine process to remove the contaminants to the
desired levels.
The acid gas (CO2 with trace sulphur, hydrocarbons and amine compounds) passes
through a thermal oxidiser to destroy pollutants prior to discharge to atmosphere.
Each LNG Train uses a dedicated AGRU.
The heat required for thermal regeneration of the amine is obtained from waste heat from
the refrigerant compressor gas turbine drives.
A common storage tank provides solvent storage for both AGRUs.
Dehydration
The Dehydration Unit reduces the water content of the feed gas in order to prevent
freezing and potential blockages in the cryogenic sections of the plant. The dehydrator
beds use regenerable molecular sieve technology - a slipstream of treated gas is heated
against hot oil and used to regenerate the molecular sieves.
The heat required for thermal regeneration of the dehydration desiccant is obtained from
waste heat from the refrigerant compressor gas turbine drives.
Each LNG Train uses a dedicated Dehydration Unit.
NGL Extraction Unit
The NGL Extraction Unit removes heavy hydrocarbons - particularly benzene and heavy
aliphatic hydrocarbons (C5+) - in order to meet the treated gas specification required for
liquefaction and to avoid their freezing in the downstream cryogenic sections. The unit also
produces stabilised condensate and LPG product for storage and export. The NGL
Extraction Unit is based on open-art technology using a turbo-expander as the primary
means of chilling the incoming feed gas.
Each LNG Train uses a dedicated NGL Extraction Unit.
Gas Liquefaction
Each LNG Train uses a dedicated Gas Liquefaction Unit where feed gas is pre-cooled
against propane refrigerant before passing into the tubeside of the Main Cryogenic Heat
Exchanger (MCHE) where it is further cooled and liquefied against Mixed Refrigerant
(MR). The LNG is flashed to nearly atmospheric pressure to control nitrogen content
before being pumped to storage.
The MR is a mixture of nitrogen, methane, ethylene and propane – the exact proportions
are selected to provide the optimum liquefaction efficiency. Warm low pressure (LP) MR
that exits the MCHE is compressed and cooled against propane refrigerant. The resultant
cold high pressure (HP) MR is routed to the tubeside of the MCHE where further cooling

takes place. The cold MR is reduced in pressure and re-introduced into the shellside of
the MCHE to cool and liquefy the feed gas and the HP MR.
The propane refrigeration system utilises propane evaporating at three pressure levels
(LP, MP and HP) to supply refrigeration to the feed gas and the MR circuit. Propane from
the discharge of the propane compressor is condensed by air cooling. The three levels of
chilling are provided by a successive flash to a lower pressure level. As the pressure is
reduced, the propane boils at a colder temperature, providing refrigeration. The LP, MP
and HP propane vapour is the suction and side streams of the propane compressor.
Refrigerant Storage
The Refrigerant Storage unit provides storage for refrigerant grade ethylene and propane
for makeup as required to the refrigerant circuits of the Gas Liquefaction units.
Ethylene storage will provide ethylene to the mixed refrigerant (MR) circuits. Propane
storage will provide propane to the propane refrigerant (PR) and MR circuits.
Ethylene is stored as a pressurized cryogenic liquid in 2 x 50% vacuum-insulated bullets.
Propane is stored as an ambient temperature pressurized liquid in 2 x 50% bullets. The

propane bullets are earth mounded.
LNG Storage and Loading
The LNG Storage and Loading units are designed to provide storage and loading facilities
to allow for continuous production of LNG at the design production rate, storage thereof,
and to enable exports of such LNG via LNG carrier. The LNG Storage and Loading Unit
will be common for both LNG trains.
LNG rundown from the production trains will be stored in two full containment LNG
Storage Tanks, with space allocated for a third future tank. Each LNG tank has a net
capacity of 190,000 m3. The following shows the principle design features of a full
containment LNG tank. Full Containment tanks have been chosen as they represent the
State-of-the-Art LNG storage choice, ensuring the risk of accidental spillage to the
environment is kept to an absolute minimum. They therefore represent the safest storage
alternative for both personnel and the environment.

The LNG Storage and Loading unit is designed to operate in two modes:
• Holding Mode: Circulation of LNG from the LNG rundown (or LNG pumped from the
LNG storage tanks) to the jetty via the LNG loading line and back to the LNG
Storage Tanks via the LNG circulation line. This ensures that the main pipework
remains cold.
• Loading Mode: LNG loading from the LNG Storage Tanks to one LNG carrier via
both the LNG loading and circulation lines.
During both modes of operation the LNG Storage Tanks may be continuously filled with
LNG rundown. Boil off gas (BOG) from the LNG Storage Tanks and SVR line (during
loading) is compressed, cooled and routed to the common HP fuel gas system.
Provision has been made in the design to allow for the installation of future truck loading
facilities.
Marine Facilities
The marine facilities will include an LNG jetty for the loading of LNG product and a Material
Offloading Facility (MOF) for the delivery of construction materials and equipment/modules
for the construction of the Project. The proposed layout of the marine facilities can be
found in Annex 5 Document Nos. 188479-400-MA-BD-00001, 188479-410-MA-05-000001
and 188479-440-MA-05-000001.
The LNG jetty consists of a single marine trestle spanning from the causeway structure to
a T-head with two LNG loading platforms. Due to its low probability, any sea ice will be
managed during operations with ice breaking tugs.

The LNG jetty comprises the following key components:
• Jetty loading platforms

• Impounding basins
• Approach and pipe trestle
• Breasting dolphins\mooring dolphins
• Catwalks
• Buildings
• Access road
The LNG berths are orientated 157° relative to True North. This orientation was
determined based on wave modelling data, and keeps the highest recurrence of the higher
energy waves as close as possible to directly on the bow of a moored LNG carrier.
The position of the LNG berths is dictated by the minimum separation distances from the
MOF to the north and the existing pipelines to the south. This has resulted in the berths
being located in deeper water than the minimum that is usually required for LNG carriers.
The Availability Study indicates low utilization of the second berth, however this has been
retained for operational flexibility.
The access channel to the LNG berth uses the naturally occurring water depths of at least
20 meters. Therefore no dredging is required.
The manoeuvring area in the vicinity of the jetty loading platform makes use of the
naturally occurring water depths of at least 14 meters. A turning circle with a diameter of
approximately two times the length of the largest LNG carrier fits within the manoeuvring
area adjacent to the jetty loading platforms.
The jetty topsides on each loading platform includes:
• Two loading arms

• One hybrid loading arm
• One vapour return loading arm
• One tower gangway
• One LNG drain drum (also serves as LNG surge vessel)
The marine facilities include a MOF that will be used for the delivery of construction
materials and equipment/modules for the construction of the Project. Once the
construction phase is complete, the MOF will be converted into a support dock housing the
necessary support vessels (tugs and line boats) for the operation of the terminal.
The MOF comprises two distinct components:
• Causeway Structure – earthen (stone) fill structure extending from the existing
shoreline, offshore to approximately the -10 meter contour where it ties into the
MOF structure. Accommodating both the roadway leading to shore from the MOF
structure and the pipe rack leading out to the LNG jetties, and
• MOF Structure – Steel sheet pile or combi pile wall infilled with earthen (stone)
material to create berthing space for both lift-off and roll-off cargo for the Project.
The MOF Structure includes two single pile or multi pile mooring dolphins to support
end-on mooring of barges at the end of the MOF Structure for roll-off operations.
It is anticipated that an LNG carrier will be loading every 3-4 days, based on a two train
facility. LNG carriers within the approved range of 125,000m3 to 265,000m3 have a length
of between 280 – 345 m and a draft of approximately 12m.
Utilities
Condensate & LPG Storage & Loading
The Condensate & LPG Storage and Loading Unit provides tank storage and loading
facilities to allow continuous production of condensate and LPG at the design capacity of
the facility and to enable intermittent export of condensate by road tanker and continuous
export of LPG by pipeline, truck or storage to support NGL extraction start-up.
Heating Medium
The Heating Medium system provides process heating via the reboilers and heaters within
the LNG facility.
One Heating Medium system per train is provided to supply the heating requirements of a
single train plus the heating requirements of the common facilities. Provisions will be
made to allow the common users to be supplied with heating medium from either Train 1
and/or Train 2 as required. Therminol 59 or equivalent will be used as the heating
medium.
Heat duty for all heating medium users, including the common areas, will be from the
Waste Heat Recovery Units located in the Propane Compressor Gas Turbine Driver
exhaust in each train. During start-up, a propane compressor in either Train 1 or Train 2
will be on full recycle in order to provide the required turbine exhaust gas for heating the
Heating Medium.
A Common heating medium storage facility will be provided for charging, drain down and
make-up purposes.
Fuel Gas
The Fuel Gas system provides a reliable source of fuel gas to users throughout the plant.
The fuel gas system is designed to meet the quality and flow requirements of the fuel gas
consumers under all operating conditions.
The primary source of fuel gas for the entire facility is a combination of LNG boil-off gas
(BOG) and end flash gas (EFG). In order to maintain the fuel gas balance as the quantity
of BOG varies between holding mode and loading mode and the demand for fuel gas
varies, additional fuel gas is sourced from pipeline gas and dehydrated feed gas. Excess
BOG is routed back into the feed gas to each liquefaction unit.
Mixing drums and heaters are provided to smooth out compositional variations and to
provide fuel gas with the required amount of superheat.

The major fuel gas consumers are the gas turbine generators (the Power Generation
Plant) and the gas turbine drives for the refrigerant compressors. Secondary users are the
flare systems and the thermal oxidiser.
The Fuel Gas system comprises an independent Train HP Fuel Gas system (one per LNG
train), a common HP Fuel Gas system, and a common LP Fuel Gas system that also
supplies LP Fuel Gas users in the LNG Trains.
Diesel Fuel System
Diesel fuel is required for the operation of engine-driven plant equipment such as firewater
pumps and emergency generators.
Diesel arrives on site in road tankers and is pumped through a filter into the diesel storage
tank. Diesel is then transferred from storage to road tankers for distribution to the users’
day tanks throughout the LNG Facility.
A separate storage facility for marine grade diesel is provided at the Marine Offloading
Facility (MOF). Marine grade diesel is unloaded from a bunkering vessel into a bunkering
diesel storage tank. Marine diesel is then transferred from storage via a filter/coalescer to
tug boats and other small vessels berthed at the MOF.
Flare Systems
The flare system enables the reliable and safe disposal of hydrocarbon vapour and liquid
streams that result from process upsets and emergencies, which, if not routed to flare,
could lead to an uncontrolled loss of containment.
The flare system is also used to dispose of the waste hydrocarbon streams that result from
operating conditions such as start-up, shutdown, venting, draining, gas purging, heating
and cooling of equipment and/or piping. Flaring during normal operation is not a design
condition.
Two separate relief and flare systems are provided for wet or potentially wet hydrocarbon
releases and dry and potentially cold releases to avoid the risk of hydrate formation or
freezing, which could cause flow restrictions or blockages of flare piping.
The design of the flare system is as per good engineering practice: piping is designed with
slopes and no pockets, and knock-out drums are provided for the efficient removal of
liquids that could either cause damaging flow regimes (‘slug’ flow) and/or result in the
release of burning liquid from the flare tip.
Liquids contained in the knock-out drums are removed by vaporisation using electric
heaters where possible. High boiling point liquids (e.g. water, hydrocarbon condensate)
are pumped to the effluent treatment unit.
The wet and dry flare stacks, including a common spare, share a common elevated derrick
structure. The flare are demountable to allow for maintenance of a flare tip without
requiring a complete shutdown of the Facility.

An independent low pressure flare is provided for the LNG Storage and Loading area due
to the very low design pressures/relief valve set pressures of equipment within these
systems. The LP flare system is not provided with a knockout drum since the relief flows
originate from boil-off gases generated from LNG storage and loading systems and are not
expected to contain liquids or be subject to condensation.
All flares shall be provided with continuous fuel gas purges with nitrogen back-up to
prevent the infiltration of air into the system.
Plant & Instrument Air System
The Plant and Instrument Air System supplies dry compressed air throughout the LNG
Facility for:
• Instruments
• Feed to the Nitrogen Generation Package
• To utility hose stations
The air dryer package will be a solid desiccant with heatless regeneration by dry air.
Nitrogen System
The Nitrogen System supplies high-purity nitrogen (99.99 % nitrogen) throughout the plant
for:
• Utility hose stations

• Continuous seal and gland purges.
• Blanketing of tanks and vessels where an inert gas blanket is required to protect the
tank contents from degradation due to exposure to atmospheric oxygen
• Nitrogen for make-up of mixed refrigerant
• Continuous and intermittent equipment purges
• Back-up gas for purging of flare and flare headers.
Nitrogen is prepared by the cryogenic distillation of air to produce gaseous nitrogen (GAN)
and liquid nitrogen (LIN). Oxygen and other impurities are vented to atmosphere.
GAN is sent to the nitrogen distribution header while the LIN at the same pressure is
stored for vaporisation and use during periods of peak demand, e.g. maintenance purging.
Truck unloading of LIN is possible for rapid refilling of the LIN storage vessel.
Fresh/Potable/Demineralised Water Systems
Three separate water systems are designed to provide buffer storage and distribution of
water at different qualities throughout the Facility.
All raw, i.e. untreated, fresh water is provided by a pipeline from the nearby Meadow Lake,
and is stored in the Raw Water Storage Tank (see below), which provides security of
supply to the LNG Facility in case the supply is disrupted. Raw water is filtered and
treated to a minimum quality prior to storage in the combined Fresh Water/Firewater
Storage Tank. Fresh Water is distributed to the following users:
• Firewater system
• Fresh Water system (utility hose stations)
• Potable Water system
• Demineralised Water system
Fresh water is further treated to produce Potable Water based on the more onerous of
Canadian Potable Water Quality Standards and WHO standards. Potable Water is
recirculated around the Facility to the buildings (toilets, showers etc.); and safety showers
and eye wash stations. Treatment consists of activated carbon filtration followed by
remineralisation (to adjust total dissolved solids content) and sterilisation (by chlorine
injection or UV lamps).
Fresh Water is also treated to produce Demineralised Water to the specifications required
for the make-up water to the AGRU and for online washing of the gas turbines. The
demineralised water treatment package is likely to consist of reverse osmosis followed by
electro-deionisation. The use of mixed resin beds with acid/caustic regeneration is not
anticipated for the relatively small volumes of Demineralised Water required.
Fire Protection Systems
A ring main distribution system provides firewater to all areas of the Facility to supply
firewater based systems i.e. water spray, sprinklers, monitors, hydrants, hose reels, foam
systems and fire tenders. Fire tenders may take suction from the fire water system via
hydrant standpipe pumper connections.
The fire water supply and distribution system shall consist of the following:
• Storage of sufficient fire water to supply 100% of the maximum demand for a period
of two hours. A secure volume of firewater is stored in the fresh water/fire water
storage tank.
• Two fresh water fire pumps, one electrically driven and one diesel driven, each
pump sized to supply 100% of the maximum fire water demand.
Two emergency back-up diesel engine driven seawater fire pumps are located on the jetty
trestle, with each pump sized to supply 100% of the maximum fire water demand, with two
electric motor driven jockey pumps to maintain pressure in the fire water ring main.
There is a gridded fire water ring main around the process units, storage tanks, utilities
and service areas, with a single line running down the trestle to the LNG loading berth
equipment.
The ring main piping shall be installed underground at a depth not less than 300 mm
below the frost line (NFPA 24) and shall be constructed from Glass Fibre Reinforced
Plastic Epoxy Resin (GRE). Pipe sizes shall ensure a residual pressure of 7.5 barg is
available at the most remote take off point in the system.
As far as practicable the fire water distribution network shall be configured to minimise the
potential for surge/water hammer. A surge analysis of the system will be undertaken
during detail design.
Effluent Treatment
The purpose of the Effluent Treatment system is to make provision for segregation by
source, collection, routing, holding, treatment (if necessary), sampling, monitoring and
disposal.
Plant design provisions will ensure that the liquid effluents are minimized, and that effluent
discharges are within the limits laid out by the World Bank Effluent Guidelines and by
Environment Canada under section 36(3) of the Fisheries Act. Examples of design
features that reduce liquid effluents are:
• The use of air cooling in preference to seawater cooling for the rejection of process
heat. This eliminates the discharge of warm seawater that may contain treatment
chemicals;
• An Electro-deionization Unit will be used to produce demineralized water rather
than a conventional ion exchange resin type. This eliminates the need for an
associated waste water neutralisation system;
• Liquid effluents from the plant will be treated (where necessary) and discharged to
the sea or taken offsite for further treatment.
The Effluent Treatment system comprises of the following elements:
• Clean Surface Water System (CSS)
The CSS collects rain and snow melt that is free of gases, hydrocarbons and
other pollutants. Offsite roads, building areas, and undeveloped areas will be
considered clean water areas. Sand traps will be provided at intervals in the
channels to remove any solid particulates before being routed to the Clean
Surface Water Pond prior to disposal via the outfall line to sea.
Solid material will be removed by vacuum trucks in a manner commensurate
with the recovered material.
• Potentially Oil Contaminated System (POS)
The POS collects rain, snow melt and firewater/wash water from paved areas of
the Facility where hydrocarbon spills or leaks, whilst not expected, could occur.
Run-off water from these areas could therefore be oil-contaminated.
Water from POS areas is collected by an underground pipe network and gravity
flows to the First Flush Basin. Manholes located throughout the system will
contain silt traps to collect sediment and prevent it from reaching the treatment
package.
Lube oil spills from machinery (such as pumps) will be contained by pump base
plates/drip pans, which will be furnished with an open drain pipe to direct spills
towards the POS.
The design of the First Flush Basin assumes that only the first flush of
rainwater/firewater is contaminated after which point the influent can be treated
as clean surface run-off. The contaminated water is pumped to the Oily Water

Treatment Package and the clean water is routed by gravity to the Clean
Surface Water Pond prior to disposal via the outfall line to sea.
Impounding Basins will be provided in areas where there is an increased risk of
large leaks. Pumps, located within the basins, will be provided to empty the
basins of rain water / snow melt in accordance with CSA Z276-15. The pumps
will route the water to the nearest manway within the POS.
• Oil Contaminated System (OCS)
The OCS collects rain, snow melt and firewater/wash water from paved areas of
the Facility where hydrocarbon spills are likely to occur, e.g. diesel handling
areas, lube oil systems etc. Water from these areas is therefore likely to
contain a significant amount of oil. Areas identified as OCS will be locally
segregated (a) to limit the volume of water that requires treatment and (b) to
prevent water runoff from OCS areas polluting POS areas. Where possible,
OCS areas are segregated within buildings or housings to prevent rain and
excessive snow melt from ingress to the sumps especially compressor and GT
drive enclosures.
Water from curbed areas where the area is likely to contain a significant volume
of oil will be contained and tested. If there is negligible contamination of the
water, the contents will be discharged to the First Flush Basin. However, if the
contents of the curb contain an oil spill then the contents will be transferred to a
vacuum truck and processed off-site.
Where it is not possible to connect equipment items to the common system; drip
trays or collection pots will be installed, the contents of which can be removed
by vacuum truck.
• Sanitary Waste
Sanitary waste water will be collected and processed in a Sewage Treatment

Unit. The sludge will be removed (off-site) and the treated effluent water will be
stored and disposed of off-site by truck or routed to the Clean Surface Water
Pond prior to disposal via the outfall line to sea.
• Hazardous Chemical System (HCS)
Water from curbed areas where the area is likely to contain hazardous
chemical(s) will be contained and tested. If the water contamination is
negligible and is considered non-hazardous, discharge will be to the First Flush
Basin, prior to disposal via the outfall line to sea. If the contents of the curb
contain hazardous chemical(s) then the contents will be transferred to a
vacuum truck and processed off site. Where it is not possible to connect
equipment items containing hazardous chemicals to a closed drain system; drip
trays or collection pots may be installed which can be pumped out and removed
by vacuum truck.

HCS areas around the amine, hot oil systems and other areas containing
chemicals will have dedicated drainage systems to collect spills.
• Oily Water Treatment
All potentially oil contaminated water is routed to the First Flush Basin together
with clean water from any of the oil contaminated, hazardous chemical curbed
areas/sumps and LNG impoundment basins.
From the First Flush Basin oily water is pumped to the CPI Separator located in
the Oily Water Treatment Package. The Oily Water Treatment Package also
treats residual liquids from the Vacuum Truck Discharge Sump. This sump is
provided to intermittently collect oily water from the Wet Gas Flare KO Drum
Pump and miscellaneous oily water slops which may be collected by truck
throughout the LNG facility. The contents of the sump are pumped to the Oily
Water Treatment Package.
The separated oil from the Oily Water Treatment Package is collected in the
Slop Oil Tank. This tank can also be used for storing spent lubrication oil prior
to offsite disposal.
Treated water from the Oily Water Treatment Package is routed to the Clean
Surface Water Pond prior to disposal to sea via the outfall channel.
• Water Supply Pipeline
Water is obtained from a pumping station installed at Meadow Lake. A study

was performed to establish the following design criteria:
§ Confirmation of Meadow Lake’s suitability as the water supply source

§ Pipeline routing selection
§ Structural and architectural building details (pumping station and
intake structure)
§ Foundation layout drawings and design
§ Pipe routing drawings
§ Pumping station mechanical and process design
§ Electrical and control requirements
§ Equipment list, equipment data sheets and
§ Specifications for piping, mechanical and electrical systems, and
building envelope.
Details of the above are contained in Annex 11.

3.1.1.2 PLOT PLANS
The following image is a 3D rendering of the Project.
The Overall Plot Plans of the site can be seen in Figures referenced below, all of which are
contained in Annex P:
Overall Site Plan – LNGC-O&U-JETTY Document No. 188479-PI-01-000001
Overall Plot Plans – LNGC & O&U Document No. 188479-PI-01-000002

Overall Plot Plan – Jetty & Berth Document No. 188479-000-PI-01-000003
More detailed Plot Plans are confidential and are supplied as confidential documents for
review for conformity by NSUARB. The documents are references:-
Area Plot Plans
The following documents for Area Plot Plans can be found in Annex 3:-
188479-000-PI-02-000001 188479-400-PI-01-000002
188479-000-PI-02-000002 188479-400-PI-01-000003
188479-100-PI-01-000001 188479-400-PI-01-000004
188479-100-PI-01-000002 188479-500-PI-01-000001

188479-200-PI-01-000001 188479-500-PI-01-000002
188479-300-PI-01-000001 188479-600-PI-01-000001
188479-300-PI-01-000002 188479-600-PI-01-000002
188479-300-PI-01-000003 188479-700-PI-01-000001
188479-400-PI-01-000001 188479-900-PI-01-000001
Air Emissions Location Plans
Details can be found in Annex 9 Document Nos. 188479-000-PI-01-000004 and

188479-000-PI-01-000005.
3.1.1.3 BLOCK FLOW DIAGRAMS
The purpose of the Overall Block Flow Diagram (as noted in Section 3.1.1.1 above) is to
illustrate the main raw material (feed gas) and products (LNG and condensate). The Block
Diagram shows the interrelationships between the different process units; major streams
are numbered (to allow cross reference to the overall heat and material balances); and, for
completeness, the utility units are shown as standalone blocks. This drawing should be
read in conjunction with the Design Basis, PFDs and UFDs.
3.1.1.4 PROCESS FLOW DIAGRAMS (INCLUDING MATERIAL AND ENERGY

BALANCES)
Process Flow Diagrams (PFD) have been prepared for all process units. PFDs show all
tagged equipment items, major control loops, major process streams (with stream
numbers to allow cross reference to the heat and material balances) and equipment tags
and descriptions. The final issue incorporates changes resulting from Process Licensor
and P&ID development.
The Overall Process Flow Diagram and all other Process Flow Diagrams are confidential
documents and are supplied as confidential for review for conformity by NSUARB, and are
contained in Annex 2.
The purpose of the Overall Heat and Material Balance is to illustrate the main raw material
(feed gas) and products (LNG and condensate). Overall Heat and Material Balances have
been prepared for the full envelope of cases which are to be expected in operation:-
Only the streams indicated on the Overall Block Flow Diagram are defined.
Pressure, temperature, flowrate, liquid and vapour properties, and overall composition are
shown for each stream. All Heat and Mass Balances are confidential and in some cases
contain redacted proprietary information and are supplied as confidential for review for
conformity by NSUARB in Annex 2 Document No. 188479-000-PR-LS-00002.

3.1.1.5 APPLICABLE CODES AND STANDARDS
The design of the LNG terminal will, at a minimum meet the Canadian Code requirements
and other North American standards including:
• Canadian Standards Association (CSA) Z276-01 “Liquefied Natural Gas (LNG) –

Production, Storage, and Handling”
• National Fire Protection Association (NFPA) 59A “Standard for the Production,
Storage, and Handling of Liquefied Natural Gas (LNG)”
• Code of Practice – Liquified Natural Gas Facilities of the Nova Scotia Department of
Energy (NSDE, 2005).
The provisions for seismic design will be adopted from the National Building Code of
Canada (NBCC) for the Safe Shutdown Earthquake.
Given that CSA Z276-11 does not explicitly address full containment storage tanks, the
provisions of the US Standard NFPA 59A will be adopted. Both CSA Z276-11 and NFPA
59A provide a comprehensive list of standards that are to be met for the design and
operation of LNG facilities and storage/containment tanks. Environmental loads will be
based on NBCC, with the provisions of CSA Z276-11 prevailing where conflict exists.
The LNG tank design basis is API 625.
NFPA 59A tanks are designed to API 625, which references API 620 and ACI 376. The
Facility is designed in accordance with CSA Z276, which is aligned with NFPA 59A with
references to API for full containment tanks.
The marine facilities will be designed and operated in general accordance with key
guidelines from the following organizations:
• Transport Canada (TC) (Technical Review Process of Marine Terminal Systems in

• Transhipment Sites (TERMPOL) process);
• International Maritime Organization (IMO);
• Safe Waterways, Guidelines for the safe design of commercial shipping channels,
Canada;
• PIANC guidelines, version 2011;
• Oil Companies International Marine Forum; and
• Society of International Gas Tanker & Terminal Operators.
• GIIGNL International Group of Liquefied Natural Gas Importers
Where there is conflict or lack of clarity between codes the following order of precedence
has been followed:
1. Nova Scotia Regulations (e.g. Nova Scotia Gas Plant Facility Regulations)
2. Canadian Regulations
3. Codes of Practice / Handbooks as associated with governing Canadian Standards
as applicable to Nova Scotia (e.g. Nova Scotia Department Of Energy Code Of
Practice, Liquefied Natural Gas Facilities Version 1 dated 13 July 2005)
4. Canadian Codes and Standards as applicable to Nova Scotia (e.g. CSA Z276-15)
5. International Codes and Standards (e.g. NFPA 59A, EN 1473, API 620).
A complete list of the Acts, Codes and Standards can be found in Annex 1 Document
number 188479-000-PE-LS-00001.
3.1.2 PROCESS INFORMATION FOR PROCESS, UTILITY AND SUPPORT

SYSTEMS
3.1.2.1 PIPING AND INSTRUMENT DIAGRAMS (PIDS)
Piping and Instrument Diagrams are confidential and are supplied as confidential
documents for review for conformity by NSURB and are contained in Annex 2.
3.1.2.2 RELIEF SYSTEM DESIGN AND DESIGN BASIS
All equipment and piping systems are protected against overpressure by mechanical
devices such as PSVs or bursting discs.
Where required, equipment and piping systems are protected against under pressure by
vacuum breakers. The use of vacuum breakers is normally restricted to storage tanks that
operate at a nominal atmospheric pressure.
Emergency blowdown valves are provided to reduce the pressure in the equipment to
ensure the coincident pressure and metal temperature does not cause the allowable
stress to be exceeded.
Emergency blowdown facilities are provided on:
• All equipment/piping systems containing 4 m³ of butane or lighter liquids trapped

between ESD valves and/or valves which can be remotely closed, which could be
subject to a sustained fire.
• All equipment or piping systems containing at least 3 tonnes of hydrocarbon gas
with a maximum operating pressure of 690 kPag or higher (based on the high-high
pressure trip), trapped between ESD valves and/or valves which can be remotely
closed, which could be subject to a sustained fire.
The Relief system has been designed to be in accordance with the API 520 “Sizing,
Selection and Installation of Pressure Relieving Devices” and API 521 “Guide for Pressure
Relieving and Depressurisation Systems” and the relevant sections of code CSA Z275-15.
3.1.2.3 VENTILATION SYSTEM DESIGN AND DESIGN BASIS
All buildings will be heated and air conditioned. The FEED Package provides the basic
design principles to design, supply, install, test and commission the different HVAC
systems. Supplier’s standard systems will be used and will be required to be compliant

with all national and local codes and regulations. The HVAC Philosophy is contained in
Annex 6 Document No. 188479-000-ME-PH-00002.
3.1.2.4 BASIC PROCESS CONTROL SYSTEM
The Process Control System is described in the various philosophy documents which
define the basis for the detail design of the instrumentation, control and safety systems for
the Facility, but in particular in the Instrument and Control Philosophy Document No.
188479-000-IC-PH-00001 contained in Annex 8. This philosophy also defines the
systems supplied by package equipment vendors and associated interfaces of these
systems with the plant control system as well as the methods to be used for the control of
the facility and the principle features of the instrument and control systems required. The
philosophy is based on a concept of using proven control and protection strategies and
equipment.
3.1.2.5 SAFETY INSTRUMENTED SYSTEMS
In order to establish the safety levels of all process safety loops, a SIL study was
performed following the HAZOP of the FEED design. As a result of this study, each loop
was allotted an appropriate Safety Integrity Level (SIL) according to IEC 61508/61551
which the design and implementation will fulfil. The results of this study are contained in
the SIL Assessment Review, Document No. 188479-000-SE-RP-00015 in Annex 9.
3.1.2.6 INTERLOCK CAUSE AND EFFECT CHART
The Interlock Cause and Effect Charts have been developed for the overall Emergency
Shutdown Systems (ESD) and for individual units as well as utilities required to operate
the Facility. The ESD Philosophy is contained in Annex 2 Document No. 188479-000-PR-
PH-00004.
3.2 PROCESS HAZARD ANALYSIS
The overall Safety & Environmental Engineering goal is to provide a proven and
demonstrably safe working facility that is designed in the manner recommended by safety
requirements of CSA Z276-15 “Liquefied Natural Gas (LNG) - Standard for Production,
Storage, and Handling” as well as Nova Scotia’s Gas Plant Facility Regulations. In
addition the safety control systems will comply with relevant NFPA and API codes and all
Canadian legal requirements.
Hazards are managed based on the hierarchy of:
1. Inherent safety/elimination,
2. Prevention,
3. Control,

4. Detection
5. Mitigation,
6. Emergency response.
All hazards shall be identified and assessed in accordance with the guidance provided by
good engineering practice, and with the objective of inherent safety by hazard elimination
applied early in the design so far as is reasonably practicable.
The FEED design implements an appropriate combination of inherent safety, prevention,

detection, control and mitigation systems. Systems that are provided to protect personnel
are suitable for the hazardous events and have design standards commensurate with the
required risk reduction. The design, operation and maintenance of these systems will be
undertaken by competent people who understand their responsibilities in the management
of the hazards.
The hazard management process started in FEED will continue throughout the installation
lifecycle. Any changes to the facility which may affect the likelihood or consequences of
hazards will be identified and assessed, and the management systems revised as
necessary. The hazard management process will be documented and communicated to
everyone involved in the design of the facility to ensure they have sufficient knowledge of
the hazards and their contribution to the overall risks.
The hazard management system proposed in the FEED for ongoing deployment operates
as follows:
• Systematically identify hazards, using HAZIDs, HAZOPs, technical reviews, etc.

• Eliminate hazards where possible and practicable.
• Provide suitable measures to prevent, detect, control or mitigate hazards that
cannot be eliminated.
• Provide adequate means for personnel escape and recovery from major accidents.
• Evaluate risks to personnel via qualitative or quantitative risk assessment.
• Assess the benefits of identified risk reduction measures.
In addition to the hazard management system described above, other safety

studies completed during the FEED included:
• Consequence modelling.
• Quantitative Risk Assessment (QRA) studies.
3.2.1 HAZOP
A preliminary HAZOP study (as contained in Annex 9 Document No.188479-000-
SE-RP-00001) was held during the FEED design phase of the project. It was led by
an independent third party and was conducted by a team including representatives
from CB&I and Pieridae from engineering, operations, maintenance,
instrumentation and control.
The HAZOP review covered all of the LNG process facilities from the interface point
with the feed gas supply line to the loading arms.
In addition to the process facilities the following utility systems were also studied
• Firewater
• Fuel Gas System
• Heating Medium System
Vendor packages and utilities (except as described above) were considered to be
outside the scope of these preliminary HAZOP reviews.
The HAZOP study did not identify any issues which were judged to be significant
enough to jeopardise the project or to warrant additional detailed study.
Where drawings representing typical details were provided, e.g. compressor seals
and hook up drawings, it was recognised that these details are dependent on the
selected machine supplier and as such these were not studied during the HAZOP.
The HAZOP study raised a total of 77 actions. Initial responses have been
provided to the actions, i.e. indication of how the actions shall be completed during
the detailed design phase.
Following the completion of the HAZOP, a preliminary Safety Integrity Level (SIL)
Assessment study was completed. The SIL Assessment covered all of the systems
that were studied during the FEED HAZOP.
The following confidential documents contain the procedure and results of the
HAZOP activities:
• HAZOP Study Report
• SIL Assessment Report (see section 3.1.2.5)
A review of the HAZOP together with additional analysis of any design changes will be
made at stages throughout the detailed design and periodically throughout the operational
phase.
3.2.2 MANAGEMENT OF CHANGE
To address the Code of Practice requirements for Management of Change the project will
follow a Safety and Environmental Action Tracking and Closure Process.
3.2.2.1 INTRODUCTION
Safety and Environmental Actions are generated from studies and design reviews such as:
• PHRs/HAZID (Process Hazard Review/Hazard Identification) Reviews

• PHAs/HAZOP (Process Hazard Analysis/Hazard and Operability Study)
• Plot Plan Reviews
• Ergonomic Evaluations
• Model Reviews
• Hazardous Area (Area Classification) Reviews
• Recommendations stated in Safety and Environmental reports

Each action will be recorded and assigned to an owner for resolution. The actions,
responses and tracking information will be held in a Safety and Environmental Action
Register.
3.2.2.2 TASKS AND RESPONSIBILITIES

This section describes the various responsibilities in the action tracking and closure
process.
3.2.2.2.1 Engineering Management

The status of all the Safety and Environmental Actions will be reviewed by Engineering
Management and the status of their resolution and closure will be communicated to the
Project via project reports and periodic meetings.
Engineering Management will also ensure the relevant actions resulting from studies and
design reviews etc. are formally transmitted to the Lead Safety and Environmental
Engineer for action tracking. Actions will be assigned to Engineering Disciplines and the
resolutions expedited. Engineering Management will finally provide final approval of the
proposed resolution.
3.2.2.2.2 Safety and Environmental Engineering

Overall coordination of the action tracking and documentation process on the project is the
responsibility of the Safety and Environmental Engineering Discipline along with the direct
responsibility for, and management of, safety and environmental action tracking and
closure. They will also approve the proposed resolutions of the relevant actions.
3.2.2.2.3 Safety and Environmental Action Coordinator

A Safety and Environmental Action Coordinator will be appointed to functionally manage
the Change Process. Their responsibilities will include:
• Transmittal of the actions to the responsible party;

• Review of the actions responses and any supporting documentation for
completeness and satisfactory resolution of the action; arranging for meetings to
review action responses, where necessary;
• Submit actions for acceptance and approval of proposed resolution;
• Maintain the Safety and Environmental Action Register and associated tracking
logs
3.2.2.2.4 Lead Discipline Engineer

The Lead Discipline Engineer is required to develop and proposes an acceptable
resolution for assigned actions and coordinate with other Disciplines as required. They will
provide complete answers to actions, including copies of supporting documentation and
will implement actions under their responsibility once the proposed resolution has been
accepted. They will also provide all verification documentation to support implementation
of actions to the Safety and Environmental Action Coordinator.
3.2.2.2.5 Owner Representatives

For actions that are assigned to the owner, the Owner’s representative fulfils the role of the
Lead Discipline Engineer in responding to the Actions.
Depending on the nature of the action, the Owner may also be required to review and
approve the final action or the overall approves the Safety and Environmental Action Close
Out Report.
3.2.2.2.6 Non-Engineering Functions

Actions with an impact on Engineering but that are outside the engineering scope may
require to be assigned to other Functions for a response, (for example, Construction,
Commissioning, Subcontracts, Procurement). In this case, the appropriate project lead for
the Function fulfils the role of the Lead Discipline Engineer.
3.2.2.2.7 Site Engineering

It may not be possible to close all actions before the Engineering activities are transferred
to site. In this case the Field Engineering Manager fulfils the role of Engineering
Management with suitable support for overall coordination, tracking, management and
closure also transferred to relevant project site personnel.
3.2.3 PRE-START UP SAFETY REVIEW
A Precommissioning & Commissioning (PCC) team will be mobilized during the

development of the Project. This team will liaise with Engineering, Procurement, QA, HSE
and Construction teams for planning the precommissioning, commissioning and start-up
work. The PCC team will be mobilized to site to suit the Project Schedule and progress of
the Work. At site, the Precommissioning and Commissioning (PCC) team will hand over to
the Start-Up and Initial Operations (SUIO) team at Ready for Start-Up (RFSU). The SUIO
Team will have the responsibility for the start-up and initial operations of the LNG Plant.
The SUIO team will hand over to the Operations and Maintenance (O&M) team at
Substantial Completion (SC). The Completions Handover covers the precommissioning,
commissioning, start-up, testing and initial operations and maintenance of the LNG Plant
up to Substantial Completion of each LNG Train. The procedures for ensuring safe
operation during the start-up procedure are contained in the Precommissioning and
Commissioning Philosophy contained in Annex 10 Document No. 188479-000-CM-PH-
00003. These will be reviewed and extended during the course of the project development
to ensure that all procedure remain fit for purpose.
3.2.4 OPERATING PROCEDURES (CSA Z276-01 CLAUSE 12)
The Operational Philosophy for the Facility is contained in Annex 10 Document No.
188479-000-CM-PH-00002. This should be read in conjunction with the Maintenance
Philosophy in Annex 10 Document No. 188479-000-CM-PH-00001 which outlines other
operational procedures of the plant with regard to maintenance. During the course of the
projects implementation detailed operating instructions and procedures will be developed
to ensure a safe operation of the plant

3.2.5 TRAINING (CSA Z 276-01 CLAUSE 3.4 AND 12.5)
The Philosophy for training of personnel during the design, construction, commissioning
and operation of the plant is described in the confidential document 188479-000-CM-PH-
00005 included in Annex 10 for assessment by NSURB. Prior to operational start up a
programme of continual learning will be developed to address any training issues that may
occur during the operational lifetime of the plant.
3.2.6 MECHANICAL INTEGRITY (CSA Z276-01 CLAUSE 12.4 AND 12.5)
Pieridae’s QHSE is contained in Document No. GPL-PEL-PMG-PRO-0001 “Goldboro LNG

Project Quality Management System” contained in Annex 2 describes how the Project’s
operations organisation will implement the Pieridae quality management system
requirements within the organisation. The QHSE procedure described is consistent with
the Pieridae Energy Ltd Management system requirements which are based on ISO
9001:2015, ISO14001 and OHSAS 18001 management systems it applies to all activities
of Goldboro LNG Project.
The overall responsibility for implementing the procedures will sit with the Project
Manager.
He is also responsible for:
• Ensuring the activities required for operating the organisation are planned
implemented and controlled, and their progress monitored.
• Determining the sequence and interaction of the processes applicable.
• Communicating requirements within the organisation, customer and interested
groups, and resolves issues that arise at the interfaces of such groups.
• Participate in reviews of management system data i.e. audit results, corrective
actions, preventive actions etc. and approving actions.
• Ensuring that where some services may be outsourced the responsibility for the
quality of those services remains with Goldboro LNG Project.
Quality Assurance will be used to control designer, fabricator and constructor competence
requirements for the LNG Plant and tank construction together with inspection and testing
requirements, also identifying qualifications of quality assurance personnel, welder
qualifications, and for inspection and testing of piping.
Potential suppliers will be pre-qualified to ensure that they have a satisfactory quality
assurance program. Prior to start of construction, the requirements for welding, fabrication,
and non-destructive examination (NDE), including tests and inspections, their frequency
and acceptable limits will be defined and appropriate procedures developed. Approvals,
qualification of employees, hold and witness points, and audits will be defined in the main
EPCC QA Plan prior to commencing work.

Fabrication records shall be verified for accuracy and completeness by Pieridae prior to
installation of equipment.
3.2.7 INCIDENT INVESTIGATION
The QHSE procedures will be developed to outline the processes by which any excursions
from accepted standards during construction and operation will be identified and
corrected.
3.2.8 EMERGENCY PLANNING & RESPONSE (CSA Z276-11 CLAUSE 13.3.3)
An emergency response plan will be developed following the finalisation of the detailed
design for use in the operational phase and will address issues including, but not limited
to, the following:
• Operating malfunctions
• Structural collapse of part of the Facility
• Personnel error
• Force Majeure events
• Activities carried out adjacent to the Facility.
The emergency response plan will address procedures for ensuring that any harm to
personnel or the general public is minimized, that appropriate local officials are notified in
the event of a possible need to evacuate persons from the vicinity of the Facility, and to
protect the Facility in the event of any emergency. The Facility’s design includes the
provision of “First Response” emergency services on site. Pieridae will form a working
group with all the relevant stakeholders (e.g. Fire Department, Coastguard, etc.) to ensure
that responses to any “event” are coordinated and practiced prior to the Facility going into
operation.
3.2.9 AUDITING (GAS PLANT FACILITY REGULATIONS SECTION 20)
Scheduled Audits prior to commissioning and throughout operation, will be developed in

an audit scheduling programme carried out by Pieridae’s QHSE department.
Audits will concentrate on any variations in the processes and consider improvements
and/or their suitability as well as implementation and understanding of the procedures.
Audits on any identified risk actions will focus on their effectiveness and implementation.
Pieridae will define the criteria and scope of such audits in conjunction with the concerned
auditees, and in conjunction with requirements of the Gas Plant Facility Regulations, any
terms or conditions of a Licence to Operate, CSA Z276-01 and the Code of Practice –
Liquified Natural Gas Facilities. Complete records of each audit will be maintained.
Corrective actions and preventative actions, where identified, shall be agreed by all parties
at the time of audit and a date for completing actions agreed. Follow up activities shall
include verifications of the actions taken and the reporting of the verification results. These
results will be stored and made available to the relevant authorities, as appropriate.
During an audit the auditor will record non-compliance to any particular requirement within
procedures, specifications, process or product and agree the corrective/preventive actions
and due dates for completions with the auditees. The auditor will be looking to the
stakeholder to implement procedures for corrective and preventative actions for:
• Reviewing nonconformities, including complaints from the Project

• Determine the causes of the non-conformity
• Evaluating the need for action to ensure that the non-conformities do not recur
• Determining and implementing the actions needed
• Records of the actions taken, and
• Review of the corrective / preventative actions taken.
4 FEED
The concept selection was performed prior to developing the FEED which reviewed
different options for critical aspects of the plant design and established the preferred
options based on environmental impact; proven operation; CAPEX and OPEX; and
retaining flexibility for ongoing project development.
Critical aspects reviewed were:
• Preliminary feed gas and LNG product specifications
• Technology selection for:
o Acid gas removal
o Mercury removal and dehydration
o Heavy hydrocarbon removal
• Selection of liquefaction process:
o Refrigerant(s)
o Refrigerant compressor driver selection
• LNG storage concept – number, size and type of tank
• Power generation concept
• Cooling medium (air vs. water)
• Heating medium
• Utility concept
• Conceptual layout
• Marine terminal – length of jetty trestle, number and orientation of berths
• Layout
• Execution
The FEED design for the Goldboro LNG Project includes the following units and facilities:-
• Inlet Facilities common to both LNG Trains
• Two LNG Trains, each with a nominal capacity of 4.8 Mtpa. The selected
liquefaction technology is APCI’s C3MR (propane precooled mixed
refrigerant) technology in a Split MR™ process configuration
• Two full containment LNG storage tanks, each with a capacity of 190,000m3,
with provision of space for a future third tank
• Storage for ethylene and propane refrigerant; hydrocarbon condensate; and
LPG
• Truck loading facilities for condensate export. Provision of space for future
LNG truck loading
• Jetty trestle and two berths for the mooring and loading of LNG carriers
ranging from 125,000 to 265,000 m³ capacity
• Material Offloading Facility (MOF) for the delivery of equipment and
construction materials. Once construction is complete, the MOF will revert to
a self-contained support dock for the tugs, line boats and other small craft
required to support the loading of the LNG carriers
• Power Generation – will be executed using aeroderivative gas turbine driven
generators in combined cycle. Island-mode operation with no connection to
the external grid
• Essential Power Diesel Generators
• Boil-off gas and fuel gas systems
• Hot oil heating medium
• Other Utilities – air, nitrogen, water
• Fire Detection, Gas Detection, Low Temperature & Spill Detection and Fire
Fighting
• Integrated Control and Safety System (ICSS)
• Telecommunication and Security Systems
• Plant Infrastructure, roads and drainage
• Buildings – plant buildings, offices/administration, central control room,
substations, local equipment rooms etc.
• Site Preparation, Civil Design
• Security Facilities – buildings, fencing
• Construction Facilities - temporary buildings, haul roads etc.
As part of the FEED study the following issues were also examined and their impact
assessed:
• Spur pipeline providing the connection from the battery limits of the facility to
the existing M&N Pipeline, Pig Receivers, and Manifold

• Possible LPG export lines
• Ship design and development. (Impact on design considerations)
• Raw Water supply from Meadow Lake to the Facility’s battery limits including
pipeline and all utilities and appurtenances
• Diversion of Highway 316
• Relocation of existing facilities or infrastructure such as helipad or wind
turbines
• Relocation or mitigation for sensitive or endangered species
• Contaminated soils survey and disposal
• Unexploded ordinance survey and disposal
• Grid or utility spurs required beyond the battery limits of the facility
• Permanent Operations accommodation
• Off-site offices
• Archaeological, Social and First Nations assessment and interfaces
• Environmental Assessment Process
The fundamental conditions for the design of the plant are contained in Document 188479-
000-PE-BD-00002 “Project Basis of Design” contained in Annex 1.
4.1 CHEMICAL HAZARD INFORMATION
A number of chemical are used on site which could be considered hazardous due to their
characteristics. This may be because of explosive nature, or toxicity. In particular, the
following chemicals that are present on site have been identified:
• aMDEA
• Propane
• Ethylene
• LNG
• LPG
Safety data sheets and information on chemical interactions are included in 188479-000-
PE-PR-00004 Management of Chemicals (Storage and Compatibility) Annex 9 for all of
the above. All are standard when designing and operating an LNG Facility, so that the
safety issues involved are well known and understood. From the first phase of the design,
care has been taken to minimize the risk involved in working with these chemicals, in
particular in terms of segregation and impounding to prevent accidental spillages
becoming a hazard to the environment or personnel. The general philosophy for handling
of chemicals is contained in the above document. Further to this the issues raised in this
document were considered during the project design phase.
A FEED HAZID/ENVID Study was conducted in accordance with CB&I Engineering

Procedure CMS-830-10-PR-00003 Process Hazards Review (PHR)/HAZID Study and
Document No. 188479-000-SE-RP-00009 HAZID ENVID Terms of Reference. Contained
in Annex 9.
The HAZID/ENVID Study was a key step in the design process to ensure the facility’s
design intent and critical design features were aligned with Safety and Environmental
regulatory requirements and industry standards (i.e. ISO 17776 and CSA Z726-15) and
will not adversely affect the integrity and operating conditions of the Facility.
The scope of the FEED HAZID/ENVID Study included:

• Gas inlet facilities
• LNG liquefaction
• LNG storage
• Marine LNG loading
• Road loading (condensate and future LNG)
• Refrigerant storage
• Flare facilities
• Utilities, administration buildings and workshops
In addition, the HAZID/ENVID Study also included high level interface issues with the
incoming feed-gas pipeline.
54 points were raised which required immediate action during the FEED phase or later
action during detailed design, dependent upon the severity of the impact. No issues were
identified which could not be mitigated through engineering design. The implementation of
the HAZID/ENVID will be ongoing through the project design phase and where significant
changes may be made further HAZID/ENVID activity may be required.
The HAZID/ENVID Study Report is contained in Annex 9 Document No. 188479-000-SE-
RP-00008.
More detailed information on the chemicals involved in the Facility and the process
chemistry involved is contained in Section 3.1.1.1.
4.2 PROCESS CHEMISTRY AND SYSTEMS

See section 3.1.1.1 for a detailed summary of the process chemistry and systems.
4.3 PLOT PLANS FOR SITING AND LAYOUT

The plot plan contained in Annex P shows the location of all major components of the
Facility.
4.4 PLOT PLAN FOR LAYOUT OF FIRE PROTECTION SYSTEM

Please see Section 3 above.

4.5 PLOT PLAN FOR LAYOUT OF DETECTION, CONTROL AND
INTERLOCK SYSTEMS
The Plot plan for Detection, Control and Interlock Systems is confidential and is supplied
as a confidential document for review for conformity by NSURB and is contained in Annex
9.
4.6 PLOT PLAN OF SPILL CONTAINMENT AND DRAINAGE

The Plot plan for Spill Containment and Drainage Systems is confidential and is supplied
3.
4.7 PLOT PLAN OF AREA ELECTRICAL CLASSIFICATION

The Plot plans for Area Electrical Classification is confidential and is supplied as a
confidential documents for review for conformity by NSURB and is contained in Annex 7.
4.8 BLOCK FLOW DIAGRAM OF ISOLSATION AND SHUTDOWN

SYSTEMS
The Block Flow Diagram of Isolation and Shutdown Systems is confidential and is supplied
8.
4.9 PROCESS FLOW DIAGRAMS

Process Flow Diagrams are confidential and are supplied as confidential documents for
review for conformity by NSURB and is contained in Annex 2.
4.10 PIPING AND INSTRUMENT DIAGRAMS (PID)

Piping and Instrument Diagrams are confidential and are supplied as confidential
documents for review for conformity by NSURB and is contained in Annex 2.
4.10.1 EQUIPMENT
An Equipment List for major process components can be found document 188479-000-
PE-LS-00003 “Goldboro LNG FEED Master Equipment List” in Annex 1.
4.10.2 PIPING
A description of the piping types used can be found in Annex 6 Document Nos. 188479-
000-PI-SP-00005 and 188479-000-PI-SP-00006.
4.10.3 BUILDINGS
Regulations, Codes and Standards
All buildings shall be designed and detailed in accordance with the requirements of CSA
Z276-15 and Nova Scotia Department of Energy Code of Practice, Liquified (sic) Natural
Gas Facilities Version 1 supported by NFPA 59A where necessary. The design shall be in
conformance with the National Building Code of Canada (NBCC) with a clearly defined

Seismic Force Resisting System (SFRS) that can resist 100% of the earthquake loads and
their effects in accordance with NBCC.
Industrial Practices
NS – Department of Energy Code of Practice for Liquefied Natural Gas

Facilities
Canada Occupational Health and Safety

SOR / 86-304 Regulations
SOR / 87-612 Canada Oil and Gas Occupational Health

and Safety Regulations
SOR / 94-651 Energy Efficiency Regulations
NS Reg. 400/2008 as amended by NS Reg. Energy Efficient Appliances Act

172/2012
CSA Z276-15 Liquefied Natural Gas – Production,

Storage & Handling
NFC 2010 National Fire Code of Canada
NBC 2010 National Building Code of Canada
NPC 2010 National Plumbing Code of Canada
CSA C22.1-15 Canadian Electrical Code, Part 1
ASCE Design of Blast Resistant Building in

Petrochemical Facilities – Section 3.5
NFPA 10 Portable Fire Extinguishers
NFPA 13 Standard for Installation of Sprinkler

Systems
NFPA 14 Installation of Standpipe and Hose Systems
NFPA 20 Standard for Installation of Stationary

Pumps for Fire
NFPA 25 Standard for the Inspection Testing and

Maintenance of Water Based Fire
Protection Systems
NFPA 59A Standards for the Production, Storage &

Handling of Liquified Natural Gas
NFPA 72 National Alarm and Signalling Code

A Building List detailing overall size and function is contained in Annex 4 Document No.
188479-000-CA-LS-00001. This list will be further developed in the EPCC Phase with
input from the selected buildings sub-contractors.
4.11 APPLICABLE CODES AND STANDARDS

Please see Section 3.1.1.5.
4.12 RELIEF SYSTEM AND SIZING BASIS

4.13 VENTILATION SYSTEM DESIGN AND SIZING BASIS

Please see Section 3.1.2.3
4.14 BASIC PROCESS CONTROL SYSTEM

4.15 SAFETY INSTRUMENTED SYSTEMS

4.16 INTERLOCK CAUSE AND EFFECT CHART

4.17 DESIGN AND SAFETY STUDIES

The Design, Safety and Environmental Engineering Philosophy being Document No.
188479-000-SE-PH-00001 contained in Annex 9 defines the overall safety philosophy for
the Project, and identifies the relevant documents for reference on specific aspects of the
Project.
4.18 ELECTRICAL POWER SYSTEMS

The Facility is an “island” site, in that the power generation and distribution systems are
self-contained and there is no connection to an external grid.
Power is generated by a dedicated power plant using fuel gas from the process facilities.
The plant intends to use state of the art aeroderivative gas turbines in open or combined
cycle. The actual configuration is still being designed to optimize the flexibility and
minimize CO2 production during operation. The maximum installed power output of the
plant will be approximately 190 MWh.
The Electrical Design Philosophy contained in Annex 7 Document No. 188479-000-EL-

PH-00001, describes the codes, standards and basic criteria needed to design the
electrical systems and equipment for the Facility.
The Electrical Design Philosophy addresses the following topics:
• Power Distribution and Control - describes the plant electrical power distribution
system and the control philosophy related to different electrical equipment including

HV and LV switchgear, transformers, essential generator and electrical control
system.
• Electrical Protection - describes the basic protection functions to be adopted for the
electrical power generation and distribution systems to determine the existence of
faults and to control the relative switchgear to isolate any faulty equipment within
the shortest possible time.
• Grounding & Lightning Protection - describes the philosophy regarding grounding
and lightning protection in the plant.
• Lighting - describes the philosophy for providing normal and emergency illumination
in the plant including lux (illumination) level.
• Heat Tracing - describes the philosophy and criteria to be followed during the
design of the heat tracing system.
• Cable Sizing - describes the philosophy for determining the minimum cross
sectional area of the standard HV and LV cables to be installed on the project. The
document will define the standards and procedures to be used for the design of
electrical cable.
4.19 COMPLIANCE WITH REGULATIONS

Pieridae believes it has and will continue to comply with all applicable regulations, as
noted within this application. It is also working to satisfy all conditions of its Environmental
Assessment Approval and will continue to engage all government bodies, such as
Transport Canada, to secure all necessary permits and consents for the safe construction
and operation of the Goldboro LNG Plant.
5 CLIMATOLOGY AND SITE STUDY

5.1 SITE STUDY
Details of the Geotechnical design parameters used in the design of the plant are
contained in Document 188479-000-CV-DB-00001 “Geotechnical design Basis” in Annex
4
5.2 CLIMATOLOGY STUDY

Details of the climatic design parameters used in the design of the plant are referenced
below and contained in Annex 4 and 1:
• Document No. 188479-000-CV-DB-00008 “Wind design Basis”
• Document No. 188479-000-PE-BD-00002 “Project Basis of Design” for
meteorological design
6 SEISMIC REVIEW
Historical records of earthquake location and felt intensities indicate the Goldboro site is in
a region of low earthquake occurrence, with only a few, moderate -to low-magnitude
earthquakes known within about 300km of the site. Geological analysis indicates that the
major tectonic events associated with fault movement and fold growth occurred more than
200 million years ago, and in a stress field unrelated to that of the present day. Large
differential displacements associated with coseismic surface fault rupture is not considered
as a geologic hazard at the Goldboro site.
The seismic source model for the Goldboro site consists of five area sources from the R
source zone model and three area sources from the H source zone model for Canada
developed by Adams and Halchuck (2003, 2009) PHSA was undertaken to develop %5-
damped, site-specific horizontal acceleration response spectra. The PSHA was carried
out on two reference site conditions. The first reference site condition was a weak rock site
condition assumed to have an average shear wave velocity in the upper 30m (Vs, 30) of 760
m/s (site Class B). The second reference site condition was a stiff soil site condition
assumed to have a Vs,30) of 520 m/s (Site Class C).
Site-specific spectral acceleration values (5%-damped) were evaluated for return periods
of 475 and 2,475 years, respectively. The site-specific PSHA results indicate soil Site
Class B PGA values of 0.052g and 0.120g for 475 and 2475 return periods, respectively.
The sire specific PSHA results indicate soil Site Class C PGA values of 0.057g and 0.132g
for 475 and 2475-year return periods, respectively.
The deaggergation of the 2475-year PGA and 0.2-second spectral acceleration indicates
that the major contributors to the hazard are moderate earthquakes (M6) about 100 km
from the Goldboro site. The largest contributors to spectral acceleration with longer
spectral periods (one second) are large magnitude earthquakes at distances greater than
150km from the Goldboro site.
The shear wave velocity was measured at five borehole locations at the Project’s site. The
locations are at borings BH18 (Train1), BH21 (Train 1), BH24 (Train 2), BH48 (LNG Tank
2), and BH55 (LNG Tank 1). The VS,30 of the five locations ranged from 914 m/s to 1.755
m/s. The site specific PSHA analysis was performed for the measured Vs,20’s at these five
locations. The 2,475-year return period PGA ranged from 0.085g to 0.115g.
Dynamic response analyses were performed at five borehole locations using the one-
dimensional equivalent-linear elastic dynamic response code SHAKE91 (Idriss and Sun
1992). Seven spectrally matched acceleration time histories were developed from
recorded motions. The soil input models were developed based no measured shear wave
velocities. The results of the site-specific dynamic site response analyses are presented
as acceleration response spectra at the ground surface. The amplification of the input
rock motions is dependent on the soil overburden at each location analysed. The results
of the dynamic response analysis were used to develop on design curve for the Goldboro
site.
The application of this is contained in the Seismic Basis of Design in Annex 4 Document
No. 188479-000-CV-DB-00007.

7 PRELIMINARY HAZARD AND OPERABILITY STUDY (HAZOP)
Please see Section 3.2.1.
8 FACILITY SITING AND LAYOUT ANALYSIS
A Quantitative Risk Assessment (QRA), being Document No. 188479-000-SE-RP-00013

in Annex 9, and an Explosion Assessment being Document No. 188479-000-SE-RP-
00003 in Annex 9, based on the best-available FEED data, were carried out in order to
support the FEED design.
The primary objectives of the QRA study were to:
• Determine risk to personnel from Major Accident Hazards (MAH)

• Determine the risk to the public/third party personnel from the site
• Identify main risk contributors
• Assist in decision making and comparison of design options, e.g. spacing between
main areas of the plant; impairment of critical safety functions such as Central
Control Room (CCR), Fire Station, Firewater Systems, Medical Centre/Canteen,
Administration Building
• Assist in locating permanent manned buildings and accommodation and any
temporary construction buildings should they be required; and
• Assist in demonstrating compliance with Nova Scotia – Department of Energy
(DOE), Code of Practice – LNG Facilities, (CSA) Z276-15, Project requirements
(where applicable) and best industry practices.
Major Industrial Accidents Council of Canada (MIACC)’s Risk Assessment Guidelines for
Municipalities and Industry were used to assess the LSIRs to provide advice on
assessment of acceptability of developments near the Goldboro LNG Facility.
• The MIACC’s Risk-based Land Use Planning Guidelines are presented below.
The assessment showed that a risk of 1 in 10,000 (10-4 contour) does not exceed the
fence line except for in the east and the south-east due to the proximity of LNG Train 2. In
these areas, the 10-4 contour extends onto land not owned by the Project, and impacts the
pipeline corridor.
However, these are access roads dedicated to the Goldboro LNG site and are not
expected to be used by the general public. Moreover, at present the land that falls within
the 10-4 contour does not have a permanent residential population (stationary population)
or recreational facilities such as golf courses and leisure parks that would create large
congregations of people. There is no evidence to indicate that such facilities or amenities
are planned in the future.

On the basis that the land within the 10-4 contour is not currently used, and that this pattern
of land use is likely to persist in the future, the overall LSIR contours are considered
acceptable.
The Individual Risk Per Annum (IRPA) assessment indicated that all worker categories are
below the upper tolerability limit of 10-3, and is tolerable according to industry norms for
operational staff under normal two train operation.
Radiation exceedance contours (at 10-4 per year) for 20 kW/m2, 9 kW/m2 and 5 kW/m2
were generated as part of this assessment to provide guidance on the location of
permanent and temporary buildings at the Facility.
20 kW/m2 thermal radiation can lead to incapacitation, leading to fatality unless rescue is
effected quickly. Buildings falling within this range will need to be provided with adequate
protection against thermal radiation hazards. The 20 kW/m2 does not impact the buildings
west of the LNG Trains. However, Analyser Houses, LERs and Substations within the
LNG Train area are within the 10-4 contour. These buildings are not permanently manned.
The 9 kW/m2 thermal radiation contour at an annual frequency of 10-4 per year does not
impact the Central Control Room (CCR) and Warehouse, while the Workshop and the
Laboratory buildings are marginally affected;
The 5 kW/m2 thermal radiation contour at an annual frequency of 10-4 does not impact the
Administration Building.
As a part of the building risk guidance, the 0.35 bar and 0.02 bar overpressure
exceedance contour at a frequency of 10-4 per year was generated. Occupied and
functionally significant buildings falling within this range will need to be provided with
adequate protection against overpressure hazards.

Sensitivity studies were performed to model the effect on the overall risk profile (e.g. IRPA,
LSIR etc.) of any future LNG facilities (additional BOG compressor, third LNG tank, and
LNG truck loading).
The overall impact on risk due to the additional equipment is marginal.
A SIMOPs assessment was done for the following scenarios:
1. LNG Train 1 in commissioning; LNG Train 2 under construction;
2. LNG Train 1 in operation; LNG Train 2 in commissioning.
For both cases the LSIR contours reduce since there less equipment in full operation.
However, the Individual Risk per Annum (IRPA) is above tolerable limit according to
industry norms during SIMOPS operations Phase 1 and Phase 2. The high IRPA values
are due to the assumption of long working durations (i.e. 12 hours for commissioning and
construction workers) in the train area while there are hydrocarbons present. Note that the
manning distribution used for this QRA study is a preliminary coarse estimate. A further
manning distribution review for SIMOPS phase shall be carried out in detailed design with
a view to reducing manning or hours spent in the train areas for the construction and
commissioning personnel.
In summary, the FEED QRA supports the current plot plan, particularly with respect to the
location of the buildings. The proximity of the second LNG train 2 to the eastern fence line
results in the 10-4 LSIR contour to cross the fence line into land not owned by Pieridae is
acceptable on basis that the land is not currently used and future development in that area
is not planned.
9 PRELIMINARY FACILITY AND SECURITY ASSESSMENT
Telecommunications and Security Systems
The deliverables for the Telecom and Security systems are included in the preceding
sections. For clarity, Telecoms and Security deliverables are separately summarised
below:
The following documents contained in Annex 8 (confidential) outline the security

philosophy of the plant.
• Philosophies
o Telecommunication and Security System Philosophy 188479-000-TE-PH-
00001
• Block Diagrams
o Overall Telecommunications System Block Diagram 188479-000-TE-04-
000001-01
o Security Network System Block Diagram 188479-000-TE-04-000004-01
o Corporate Network System Block Diagram 188479-000-TE-04-000005-01
o Telephone System Block Diagram 188479-000-TE-04-000006-01
o PAGA System Block Diagram 188479-000-TE-04-000007-01
o Radio System Block Diagram 188479-000-TE-04-000008-01
o Marine System Block Diagram 188479-000-TE-04-000009-01
o Security CCTV System Block Diagram 188479-000-TE-04-00010-01
o Process CCTV System Block Diagram 188479-000-TE-04-000011-01
o Perimeter Intrusion Detection System Block Diagram 188479-000-TE-04-
000013-01
o Network Management System Block Diagram 188479-000-TE-04-000014-01

10 ANNEXES

10.1 ANNEX P – PUBLIC DOCUMENTS
188479-000-PI-01-000001 OVERALL SITE PLAN - LNGC-O&U-JETTY
188479-000-PI-01-000002 OVERALL PLOT PLAN - LNGC & O&U
188479-000-PI-01-000003 OVERALL PLOT PLAN - JETTY & BERTH
188479-000-PR-05-000001 OVERALL BLOCK FLOW DIAGRAM

10.2 ANNEX 1 – PROJECT MANAGEMENT - CONFIDENTIAL AND
PROPRIETARY
188479-000-PE-BD-00002 PROJECT BASIS OF DESIGN
188479-000-PE-LS-00001 CODES AND STANDARDS LIST
188479-000-PE-LS-00003 GOLDBORO LNG FEED MASTER EQUIPMENT LIST

10.4 ANNEX 2 – PROCESS - CONFIDENTIAL AND PROPRIETARY
188479-000-PR-SK-000001 OVERALL PROCESS FLOW SCHEME - GOLDBORO LNG
188479-000-PR-01-000001 PROCESS FLOW DIAGRAM - LEGEND SHEET
PROCESS FLOW DIAGRAM - UNIT 10 - INLET FACILITIES
188479-000-PR-01-010001
AND UNIT 12 MERCURY REMOVAL
PROCESS FLOW DIAGRAM - UNIT 13 - ACID GAS

188479-000-PR-01-013001
REMOVAL - ACID GAS ABSORPTION

188479-000-PR-01-013002
REMOVAL - SOLVENT REGENERATION

188479-000-PR-01-013003
REMOVAL - COMMON STORAGE
188479-000-PR-01-014001 PROCESS FLOW DIAGRAM - UNIT 14 - DEHYDRATION
188479-000-PR-01-015001 PROCESS FLOW DIAGRAM - UNIT 15 - NGL EXTRACTION
PROCESS FLOW DIAGRAM - UNIT 15 - NGL EXTRACTION -

188479-000-PR-01-015002
DE-ETHANISER AND CONDENSATE STABILISER
PROCESS FLOW DIAGRAM - UNIT 16 - LIQUEFACTION &
188479-000-PR-01-016001
REFRIGERATION - FEED GAS PRE-COOLING
188479-000-PR-01-016002
REFRIGERATION - MCHE AND NITROGEN STRIPPER
188479-000-PR-01-016003 REFRIGERATION - MR COMPRESSION AND PRE-
COOLING
188479-000-PR-01-016004
REFRIGERATION - PROPANE COMPRESSOR & DRUMS
188479-000-PR-01-016005
REFRIGERATION - PROPANE REFRIGERATION
188479-000-PR-01-016006
REFRIGERATION - END FLASH GAS COMPRESSION
PROCESS FLOW DIAGRAM - UNIT 31 - REFRIGERANT

188479-000-PR-01-031001
STORAGE - ETHYLENE REFRIGERANT STORAGE
PROCESS FLOW DIAGRAM - UNIT 31 - REFRIGERANT

188479-000-PR-01-031002
STORAGE - PROPANE REFRIGERANT STORAGE
PROCESS FLOW DIAGRAM - UNIT 34 - LNG STORAGE &
188479-000-PR-01-034001
LOADING TANK & PUMPS
PROCESS FLOW DIAGRAM - UNIT 34 - LNG STORAGE &
188479-000-PR-01-034002
LOADING BOG COMPRESSOR
PROCESS FLOW DIAGRAM - UNIT 35 - CONDENSATE AND
188479-000-PR-01-035001
LPG STORAGE & LOADING
PIPING & INSTRUMENT DIAGRAM - LEGEND SHEET -

188479-000-PR-03-000001
GENERAL NOTES AND ABBREVIATIONS

188479-000-PR-03-000002
EQUIPMENT SYMBOLS

188479-000-PR-03-000003
GENERAL PIPING SYMBOLS

188479-000-PR-03-000004
INSTRUMENT SYMBOLOGY

188479-000-PR-03-000005
INSTRUMENT LOOP NUMBERING

188479-000-PR-03-000006
FLOW INSTRUMENT SYMBOLOGY
188479-000-PR-03-000007
PRESSURE INSTRUMENT SYMBOLOGY

188479-000-PR-03-000008
TEMPERATURE INSTRUMENT SYMBOLOGY
188479-000-PR-03-000009
LEVEL INSTRUMENT SYMBOLOGY
188479-000-PR-03-000010
VALVES INSTRUMENT SYMBOLOGY
188479-000-PR-03-000011
MOTOR INSTRUMENT SYMBOLOGY
188479-000-PR-03-000012
ANALYSERS INSTRUMENT SYMBOLOGY
188479-000-PR-03-010001 P&ID - UNIT 10 INLET FACILITIES - INLET DISTRIBUTION
188479-000-PR-03-010002 P&ID - UNIT 10 INLET FACILITIES - INLET GAS HEATER A
188479-000-PR-03-010003 P&ID - UNIT 10 INLET FACILITIES - INLET GAS HEATER B
P&ID - UNIT 10 INLET FACILITIES - INLET GAS KNOCKOUT
188479-000-PR-03-010004
DRUM
P&ID - UNIT 12 MERCURY REMOVAL - MERCURY
188479-000-PR-03-012001
ADSORBERS A/B
P&ID - UNIT 12 MERCURY REMOVAL - MERCURY
188479-000-PR-03-012002
ADSORBER AFTER FILTERS
188479-000-PR-03-013020 P&ID - UNIT 13 ACID GAS REMOVAL - SOLVENT TANK
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION -
188479-000-PR-03-016031
DEFROST GAS HEADER
P&ID - UNIT 31 REFRIGERANT STORAGE - ETHYLENE
188479-000-PR-03-031001
UNLOADING

188479-000-PR-03-031002
STORAGE BULLET A

188479-000-PR-03-031003
STORAGE BULLET B
188479-000-PR-03-031004
HEATER
188479-000-PR-03-031005
MERCURY ADSORBER AND AFTERFILTER
P&ID - UNIT 31 REFRIGERANT STORAGE - PROPANE
188479-000-PR-03-031006
UNLOADING PUMP
188479-000-PR-03-031007
DRYER AND AFTERFILTER
188479-000-PR-03-031008
DRYER REGENERATION GAS HEATER
188479-000-PR-03-031009
MERCURY ADSORBER AND AFTERFILTER
188479-000-PR-03-031010
STORAGE BULLET A
188479-000-PR-03-031011
STORAGE BULLET B
188479-000-PR-03-031012
CHARGE PUMP
P&ID - UNIT 34 LNG STORAGE & LOADING - LNG

188479-000-PR-03-034001
STORAGE HEADERS
P&ID - UNIT 34 LNG STORAGE & LOADING -

188479-000-PR-03-034003
INTERCONNECTING PIPING TANK 1
188479-000-PR-03-034004 P&ID - UNIT 34 LNG STORAGE & LOADING - LNG TANK 1
P&ID - UNIT 34 LNG STORAGE & LOADING - LNG LOADING

188479-000-PR-03-034005
PUMPS TANK 1
P&ID - UNIT 34 LNG STORAGE & LOADING - BOG
188479-000-PR-03-034009
COMPRESSOR INLET HEADER
188479-000-PR-03-034010
COMPRESSORS SUCTION DRUM
188479-000-PR-03-034011
COMPRESSOR 1 1ST STAGE

188479-000-PR-03-034012
COMPRESSOR 1 AUXILIARIES
188479-000-PR-03-034013
COMPRESSOR 1 INTERCOOLER
188479-000-PR-03-034014
COMPRESSOR 1 2ND STAGE
188479-000-PR-03-034015
COMPRESSOR 1 AFTERCOOLER
188479-000-PR-03-034020
COMPRESSOR OUTLET HEADER
P&ID - UNIT 34 LNG STORAGE & LOADING - TRESTLE

188479-000-PR-03-034021
PIPING
P&ID - UNIT 34 LNG STORAGE & LOADING - TRESTLE

188479-000-PR-03-034022
PIPING - BERTH 1
P&ID - UNIT 34 LNG STORAGE & LOADING - LOADING

188479-000-PR-03-034023
ARMS (LIQUID) - BERTH 1

188479-000-PR-03-034024
ARM (HYBRID) - BERTH 1

188479-000-PR-03-034025
ARM (VAPOUR) & DRAIN DRUM - BERTH 1
P&ID - UNIT 35 CONDENSATE & LPG STORAGE &

188479-000-PR-03-035002
LOADING - CONDENSATE STORAGE TANK

188479-000-PR-03-035003
LOADING - CONDENSATE LOADING PUMPS

188479-000-PR-03-035004
LOADING - OFF-SPEC CONDENSATE VESSEL & PUMP

188479-000-PR-03-035005
LOADING - LPG EXPORT BULLET
188479-000-PR-03-035006 LOADING - LPG EXPORT PUMPS AND METERING
PACKAGE
P&ID - UNIT 40 POWER GENERATION - MAIN POWER

188479-000-PR-03-040001
GENERATOR PACKAGE
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - COMMON HM

188479-000-PR-03-046010
BI -DIRECTIONAL HEADER
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - COMMON

188479-000-PR-03-046011
LTHM SUPPLY AND RETURN
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - HEATING

188479-000-PR-03-046012
MEDIUM STORAGE & MAKE-UP
P&ID - UNIT 46 HEATING MEDIUM SYSTEM -

188479-000-PR-03-046013
DISTRIBUTION AND FILTRATION
P&ID - UNIT 50 FUEL GAS SYSTEM - PRIMARY COMMON

188479-000-PR-03-050001
HP FUEL GAS HEATER

P&ID - UNIT 50 FUEL GAS SYSTEM - COMMON HP FUEL
188479-000-PR-03-050002
GAS HEATER
P&ID - UNIT 50 FUEL GAS SYSTEM - COMMON HP FUEL

188479-000-PR-03-050003
GAS KO AND MIXING DRUM
P&ID - UNIT 50 FUEL GAS SYSTEM - LP & HP
188479-000-PR-03-050004
DISTRIBUTION
P&ID - UNIT 50 FUEL GAS SYSTEM - LP FUEL GAS
188479-000-PR-03-050005
KNOCKOUT DRUM
188479-000-PR-03-051001 P&ID - UNIT 51 DIESEL SYSTEM - DIESEL DISPENSING
188479-000-PR-03-051002 P&ID - UNIT 51 DIESEL SYSTEM - DIESEL STORAGE TANK
P&ID - UNIT 51 DIESEL SYSTEM - BUNKERING DIESEL

188479-000-PR-03-051003
STORAGE TANK
P&ID - UNIT 51 DIESEL SYSTEM - DIESEL TRANSFER

188479-000-PR-03-051004
PUMPS
P&ID - UNIT 60 FLARE SYSTEM - DRY GAS FLARE

188479-000-PR-03-060003
HEADER
P&ID - UNIT 60 FLARE SYSTEM - INTERMEDIATE DRY GAS
188479-000-PR-03-060004
FLARE KNOCKOUT DRUM
P&ID - UNIT 60 FLARE SYSTEM - INTERMEDIATE DRY GAS

188479-000-PR-03-060005
FLARE KNOCKOUT DRUM PUMP
188479-000-PR-03-060006 P&ID - UNIT 60 FLARE SYSTEM - LIQUID FLARE HEADER

188479-000-PR-03-060007
KNOCKOUT DRUM

188479-000-PR-03-060008
PACKAGE
P&ID - UNIT 60 FLARE SYSTEM - SPARE GAS FLARE
188479-000-PR-03-060009
PACKAGE
P&ID - UNIT 60 FLARE SYSTEM - DRY LIQUID BLOW
188479-000-PR-03-060010
VESSEL
P&ID - UNIT 60 FLARE SYSTEM - WET GAS FLARE
188479-000-PR-03-060013
HEADER
188479-000-PR-03-060014
KNOCKOUT DRUM
188479-000-PR-03-060015
PACKAGE
P&ID - UNIT 60 FLARE SYSTEM - WET GAS FLARE KNOCK

188479-000-PR-03-060016
OUT DRUM PUMPS
188479-000-PR-03-060017 P&ID - UNIT 60 FLARE SYSTEM - LP FLARE PACKAGE
188479-000-PR-03-070001 P&ID - UNIT 70 AIR SYSTEM - AIR COMPRESSORS
188479-000-PR-03-070002 P&ID - UNIT 70 AIR SYSTEM - WET AIR RECEIVER
P&ID - UNIT 70 AIR SYSTEM - INSTRUMENT AIR

188479-000-PR-03-070003
RECEIVER AND DRYER

P&ID - UNIT 70 AIR SYSTEM - PLANT AIR DISTRIBUTION -
188479-000-PR-03-070004
COMMON

188479-000-PR-03-070005
DISTRIBUTION - COMMON
P&ID - UNIT 71 NITROGEN SYSTEM - NITROGEN

188479-000-PR-03-071001
PACKAGE

188479-000-PR-03-071002

188479-000-PR-03-071003
DISTRIBUTION - JETTY AND BOG AREAS
P&ID - UNIT 76 FRESH WATER SYSTEM - FRESH WATER

188479-000-PR-03-076001
TREATMENT PACKAGE
P&ID - UNIT 76 FRESH WATER SYSTEM -

188479-000-PR-03-076002
FIREWATER/FRESH WATER STORAGE TANK
P&ID - UNIT 76 FRESH WATER SYSTEM - FRESH WATER
188479-000-PR-03-076003
P&ID - UNIT 76 FRESH WATER SYSTEM - RAW WATER

188479-000-PR-03-076004
STORAGE TANK
P&ID - UNIT 77 POTABLE WATER SYSTEM - POTABLE

188479-000-PR-03-077001
WATER TREATMENT PACKAGE

188479-000-PR-03-077002
WATER STORAGE TANK

188479-000-PR-03-077003
WATER DISTRIBUTION - COMMON
P&ID - UNIT 78 DEMINERALIZED WATER SYSTEM -

188479-000-PR-03-078001
DEMINERALIZED WATER PACKAGE

188479-000-PR-03-078002
DEMINERALIZED WATER TANK

188479-000-PR-03-078003
DEMINERALIZED WATER DISTRIBUTION - COMMON
P&ID - UNIT 80 EFFLUENT COLLECTION SYSTEM -

188479-000-PR-03-080001
EFFLUENT AND STORMWATER DRAINAGE
P&ID - UNIT 80 EFFLUENT COLLECTION SYSTEM - FIRST

188479-000-PR-03-080002
FLUSH BASIN
P&ID - UNIT 80 EFFLUENT COLLECTION SYSTEM - OILY

188479-000-PR-03-080003
WATER PACKAGE
P&ID - UNIT 80 EFFLUENT COLLECTION SYSTEM - SLOP

188479-000-PR-03-080004
OIL STORAGE TANK AND PUMP

188479-000-PR-03-080008
SANITARY LIFT STATION

188479-000-PR-03-080009
SEWAGE TREATMENT UNIT

188479-000-PR-03-080010
TREATED EFFLUENT TANK AND PUMP
P&ID - UNIT 80 EFFLUENT COLLECTION SYSTEM - CLEAN

188479-000-PR-03-080013
SURFACE WATER POND
P&ID - UNIT 80 EFFLUENT COLLECTION SYSTEM - OIL

188479-000-PR-03-080016
CONTAMINATED AND HAZARDOUS CHEMICAL SYSTEM

188479-000-PR-03-080020
IMPOUNDING BASIN SUMPS AND PUMPS
P&ID - UNIT 13 ACID GAS REMOVAL - LNG TRAIN INLET

188479-000-PR-03-113001
METERING PACKAGE
188479-000-PR-03-113003 P&ID - UNIT 13 ACID GAS REMOVAL - AGR ABSORBER
188479-000-PR-03-113004 P&ID - UNIT 13 ACID GAS REMOVAL - AGR FLASH VESSEL
P&ID - UNIT 13 ACID GAS REMOVAL - AGR LEAN/RICH

188479-000-PR-03-113005
SOLVENT EXCHANGERS
P&ID - UNIT 13 ACID GAS REMOVAL - AGR

188479-000-PR-03-113006
REGENERATOR

188479-000-PR-03-113007
REGENERATOR REBOILERS
P&ID - UNIT 13 ACID GAS REMOVAL - AGR LEAN

188479-000-PR-03-113008
SOLVENT BOOSTER PUMPS

188479-000-PR-03-113009
SOLVENT COOLER

188479-000-PR-03-113010
SOLVENT CHARGE PUMPS
P&ID - UNIT 13 ACID GAS REMOVAL - AGR SOLVENT

188479-000-PR-03-113011
FILTRATION

188479-000-PR-03-113012
REGENERATOR OVERHEADS CONDENSER

188479-000-PR-03-113013
REGENERATOR REFLUX DRUM

P&ID - UNIT 13 ACID GAS REMOVAL - AGR SOLVENT
188479-000-PR-03-113014
SUMP DRUM
P&ID - UNIT 13 ACID GAS REMOVAL - THERMAL OXIDISER

188479-000-PR-03-113017
FUEL GAS KO DRUM
P&ID - UNIT 13 ACID GAS REMOVAL - AGR ACID GAS KO

188479-000-PR-03-113018
DRUM AND CONDENSABLES PUMPS
P&ID - UNIT 13 ACID GAS REMOVAL - AGR THERMAL

188479-000-PR-03-113019
OXIDISER
P&ID - UNIT 14 DEHYDRATION - DEHYDRATOR FEED GAS

188479-000-PR-03-114001
AIR COOLER
P&ID - UNIT 14 DEHYDRATION - DEHYDRATOR FEED
188479-000-PR-03-114002
SEPARATOR
188479-000-PR-03-114003 P&ID - UNIT 14 DEHYDRATION - GAS DEHYDRATOR A/B
188479-000-PR-03-114004 P&ID - UNIT 14 DEHYDRATION - GAS DEHYDRATOR C/D
P&ID - UNIT 14 DEHYDRATION - DEHYDRATOR AFTER
188479-000-PR-03-114005
FILTERS A/B
P&ID - UNIT 14 DEHYDRATION - REGENERATION GAS AIR
188479-000-PR-03-114006
COOLER
P&ID - UNIT 14 DEHYDRATION - REGENERATION KO

188479-000-PR-03-114007
DRUM AND OUTLET FILTER
P&ID - UNIT 14 DEHYDRATION - REGENERATION GAS

188479-000-PR-03-114008
COMPRESSOR
P&ID - UNIT 14 DEHYDRATION - REGENERATION GAS

188479-000-PR-03-114009
HEATER
P&ID - UNIT 15 NGL EXTRACTION - INLET GAS/GAS

188479-000-PR-03-115001
EXCHANGER
188479-000-PR-03-115002 P&ID - UNIT 15 NGL EXTRACTION - COLD SEPARATOR
P&ID - UNIT 15 NGL EXTRACTION -

188479-000-PR-03-115003
EXPANDER/COMPRESSOR
P&ID - UNIT 15 NGL EXTRACTION - BOOSTER

188479-000-PR-03-115004
COMPRESSOR
P&ID - UNIT 15 NGL EXTRACTION - BOOSTER

188479-000-PR-03-115005
COMPRESSOR AFTERCOOLER
P&ID - UNIT 15 NGL EXTRACTION - DE-ETHANISER AND

188479-000-PR-03-115006
DE-ETHANISER REBOILER
P&ID - UNIT 15 NGL EXTRACTION - STABILISER AND

188479-000-PR-03-115008
STABILISER REBOILER
P&ID - UNIT 15 NGL EXTRACTION - STABILISER

188479-000-PR-03-115009
OVERHEAD CONDENSER AND REFLUX DRUM

P&ID - UNIT 15 NGL EXTRACTION - STABILISER REFLUX
188479-000-PR-03-115010
PUMPS
P&ID - UNIT 15 NGL EXTRACTION - STABILISER LPG

188479-000-PR-03-115011
PUMPS
P&ID - UNIT 15 NGL EXTRACTION - CONDENSATE

188479-000-PR-03-115012
COOLER
P&ID - UNIT 15 NGL EXTRACTION - EXPANDER

188479-000-PR-03-115014
SEPARATOR
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - DRY

188479-000-PR-03-116001
FEED/HP PROPANE VAPORISER
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - MP/LP

188479-000-PR-03-116002
PROPANE VAPORISER
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - MAIN

188479-000-PR-03-116003
CRYOGENIC HEAT EXCHANGER - LNG CIRCUIT
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - LNG

188479-000-PR-03-116004
TURBINE
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - N2

188479-000-PR-03-116005
STRIPPER/END FLASH GAS EXCHANGER
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - LNG

188479-000-PR-03-116006
RUNDOWN PUMPS
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - MAIN

188479-000-PR-03-116007
CRYOGENIC HEAT EXCHANGER - MR CIRCUIT
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - LP MR

188479-000-PR-03-116008
SUCTION DRUM

188479-000-PR-03-116009
COMPRESSOR

188479-000-PR-03-116010
COMPRESSOR AFTERCOOLER
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - MP

188479-000-PR-03-116011
MR COMPRESSOR

188479-000-PR-03-116012
MR COMPRESSOR AFTERCOOLER
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - HP

188479-000-PR-03-116013
MR SUCTION DRUM

188479-000-PR-03-116014
MR COMPRESSOR

188479-000-PR-03-116015
MR COMPRESSOR AFTERCOOLER

188479-000-PR-03-116016
MR/HP PROPANE VAPORISER

188479-000-PR-03-116017
MR/MP PROPANE VAPORISER

188479-000-PR-03-116018
MR/LP PROPANE VAPORISER

188479-000-PR-03-116019
MR SEPARATOR

188479-000-PR-03-116020
PROPANE COMPRESSOR STRING CONNECTIONS
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - LP

188479-000-PR-03-116021
PROPANE SUCTION DRUM

188479-000-PR-03-116022

188479-000-PR-03-116023

188479-000-PR-03-116024
PROPANE COMPRESSOR

188479-000-PR-03-116025
PROPANE COMPRESSOR RECYCLE COOLER

188479-000-PR-03-116026
PROPANE DESUPERHEATER/CONDENSER

188479-000-PR-03-116027
PROPANE ACCUMULATOR

188479-000-PR-03-116028
PROPANE SUBCOOLER

188479-000-PR-03-116029
PROPANE TRANSFER DRUM AND PUMP

188479-000-PR-03-116030
DEFROST GAS HEATER AND DISTRIBUTION
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - MR

188479-000-PR-03-116032
MAKE-UP

188479-000-PR-03-116033
REFRIGERANT COMPRESSOR HOOK-UP

188479-000-PR-03-116034
REFRIGERANT COMPRESSOR GAS TURBINE HOOK-UP

188479-000-PR-03-116035
PROPANE COMPRESSOR HOOK-UP

188479-000-PR-03-116036
PROPANE COMPRESSOR GAS TURBINE HOOK-UP
P&ID - UNIT 16 LIQUEFACTION & REFRIGERATION - END

188479-000-PR-03-116040
FLASH GAS 1ST STAGE COMPRESSOR

188479-000-PR-03-116041
FLASH GAS 1ST STAGE COMPRESSOR AFTERCOOLER

188479-000-PR-03-116042
FLASH GAS 2ND STAGE COMPRESSOR

188479-000-PR-03-116043
FLASH GAS 2ND STAGE COMPRESSOR AFTERCOOLER

188479-000-PR-03-116044
FLASH GAS 3RD STAGE COMPRESSOR

188479-000-PR-03-116045
FLASH GAS 3RD STAGE COMPRESSOR AFTERCOOLER
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - EXPANSION

188479-000-PR-03-146001
DRUM

188479-000-PR-03-146002
CIRCULATION PUMPS
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - WASTE HEAT

188479-000-PR-03-146003
RECOVERY UNIT
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - LNG TRAIN

188479-000-PR-03-146004
HTHM SUPPLY & RETURN
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - LOW

188479-000-PR-03-146005
TEMPERATURE CIRCULATION PUMPS
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - LNG TRAIN

188479-000-PR-03-146006
LTHM SUPPLY AND RETURN
P&ID - UNIT 46 HEATING MEDIUM SYSTEM - HEATING

188479-000-PR-03-146007
MEDIUM RETURN TRIM COOLER

188479-000-PR-03-146008
MAINTENANCE DRAINING
P&ID - UNIT 50 FUEL GAS SYSTEM - LNG TRAIN 1 HP

188479-000-PR-03-150001
FUEL GAS HEATER

188479-000-PR-03-150002
FUEL GAS KO AND MIXING DRUM

188479-000-PR-03-150003
DISTRIBUTION
P&ID - UNIT 60 FLARE SYSTEM - TRAIN 1 DRY GAS FLARE

188479-000-PR-03-160001
HEADERS
P&ID - UNIT 60 FLARE SYSTEM - TRAIN 1 LIQUID

188479-000-PR-03-160004
COLLECTION HEADERS
P&ID - UNIT 60 FLARE SYSTEM - TRAIN 1 WET GAS FLARE

188479-000-PR-03-160011
HEADERS
P&ID - UNIT 70 AIR SYSTEM - PLANT AIR DISTRIBUTION -

188479-000-PR-03-170001
TRAIN 1

188479-000-PR-03-170002
DISTRIBUTION - TRAIN 1

188479-000-PR-03-171001
DISTRIBUTION - TRAIN 1
P&ID - UNIT 76 FRESH WATER SYSTEM FRESH WATER

188479-000-PR-03-176001
DISTRIBUTION - TRAIN.1
P&ID - UNIT 77 POTABLE WATER SYSTEM POTABLE

188479-000-PR-03-177001
WATER DISTRIBUTION - TRAIN.1
P&ID - UNIT 78 DEMINERALISED WATER SYSTEM

188479-000-PR-03-178001
DEMINERALISED WATER DISTRIBUTION - TRAIN.1
UTILITY FLOW DIAGRAM - UNIT 46 - HEATING MEDIUM

188479-000-PR-04-046001
TRAIN 1 / COMMON
UTILITY FLOW DIAGRAM - UNIT 46 - HEATING MEDIUM

188479-000-PR-04-046002
COMMON STORAGE
188479-000-PR-04-050001 UTILITY FLOW DIAGRAM - UNIT 50 - FUEL GAS COMMON
188479-000-PR-04-050002 UTILITY FLOW DIAGRAM - UNIT 50 - FUEL GAS TRAIN 1
UTILITY FLOW DIAGRAM - UNIT 51 - DIESEL SYSTEM

188479-000-PR-04-051001
COMMON
UTILITY FLOW DIAGRAM - UNIT 60 - FLARE SYSTEMS

188479-000-PR-04-060001
COMMON
UTILITY FLOW DIAGRAM - UNIT 70 - PLANT AND

188479-000-PR-04-070001
INSTRUMENT AIR SYSTEM COMMON

UTILITY FLOW DIAGRAM - UNIT 71 - NITROGEN SYSTEM
188479-000-PR-04-071001
COMMON
UTILITY FLOW DIAGRAM - UNIT 76 - RAW

188479-000-PR-04-076001 WATER/FIREWATER/FRESH WATER STORAGE & FRESH
WATER SYSTEM COMMON
UTILITY FLOW DIAGRAM - UNIT 77 - POTABLE WATER

188479-000-PR-04-077001
SYSTEM
UTILITY FLOW DIAGRAM - UNIT 78 - DEMINERALISED

188479-000-PR-04-078001
WATER COMMON
UTILITY FLOW DIAGRAM - UNIT 80 - POTENTIALLY OIL

188479-000-PR-04-080001
CONTAMINATED SEWER AND TREATMENT SYSTEM
UTILITY FLOW DIAGRAM - UNIT 80 - SANITARY EFFLUENT

188479-000-PR-04-080003
COLLECTION
UTILITY FLOW DIAGRAM - UNIT 80 - CLEAN SURFACE

188479-000-PR-04-080004 SEWER, HAZARDOUS CHEMICAL AND OIL
CONTAMINATED WATER SYSTEM
188479-000-PR-DB-000001 UTILITY DESCRIPTION
PROCESS DESCRIPTION AND CONTROL NARRATIVE -

188479-000-PR-DB-010002
INLET FACILITIES & MERCURY REMOVAL
PROCESS DESCRIPTION - UNIT 13 - ACID GAS REMOVAL

188479-000-PR-DB-013003
UNIT
188479-000-PR-DB-014003 PROCESS DESCRIPTION - UNIT 14 - DEHYDRATION
188479-000-PR-DB-015003 PROCESS DESCRIPTION - UNIT-15 NGL EXTRACTION
PROCESS DESCRIPTION - UNIT 16 - LIQUEFACTION AND

188479-000-PR-DB-016003
REFRIGERATION

188479-000-PR-DB-013002
UNIT 13 - ACID GAS REMOVAL UNIT

188479-000-PR-DB-014002
UNIT 14 - DEHYDRATION

188479-000-PR-DB-015002
UNIT-15 NGL EXTRACTION

188479-000-PR-DB-016002
UNIT 16 - LIQUEFACTION AND REFRIGERATION

188479-000-PR-DB-031002
UNIT 31 - REFRIGERANT STORAGE

188479-000-PR-DB-034002
UNIT 34 - LNG STORAGE AND LOADING

188479-000-PR-DB-035002
UNIT-35 CONDENSATE & STORAGE AND LOADING

188479-000-PR-DB-046002
UNIT 46 - HEATING MEDIUM

188479-000-PR-DB-050002
UNIT 50 - FUEL GAS
188479-000-PR-LS-00002 OVERALL HEAT AND MATERIAL BALANCE
HEAT AND MATERIAL BALANCE - LIQUEFACTION AND

188479-000-PR-LS-01604
REFRIGERATION
188479-000-PR-LS-07006 UTILITY CONSUMPTION SUMMARY - AIR & NITROGEN
188479-000-PR-LS-07603 UTILITY CONSUMPTION SUMMARY - WATER SYSTEMS
188479-000-PR-PH-00001 ISOLATION PHILOSOPHY
188479-000-PR-PH-00002 RELIEF, VENT AND DEPRESSURISATION PHILOSOPHY
188479-000-PR-PH-00004 EMERGENCY SHUTDOWN PHILOSOPHY
188479-000-PR-PH-00005 DRAINAGE PHILSOPHY

10.5 ANNEX 3 – PIPING & LAYOUT - CONFIDENTIAL AND PROPRIETARY
188479-000-PI-02-000001 AREA PLOT PLAN KEY PLAN - LNGC & O&U
188479-000-PI-02-000002 AREA PLOT PLAN KEY PLAN - MOF, JETTY & BERTHS
188479-100-PI-01-000001 AREA PLOT PLAN - LNG PROCESS TRAIN 1
AREA PLOT PLAN - EQUIPMENT LIST FOR LNG PROCESS

188479-100-PI-01-000002
TRAIN 1
188479-200-PI-01-000001 AREA PLOT PLAN - LNG PROCESS TRAIN 2
188479-300-PI-01-000001 AREA PLOT PLAN - LNG STORAGE TANKS
188479-300-PI-01-000002 AREA PLOT PLAN - REFRIGERANT STORAGE
AREA PLOT PLAN - BOG COMPRESSORS, LP FLARE GAS

188479-300-PI-01-000003
CONDENSATE STORAGE
AREA PLOT PLAN - LNG LOADING RACK, CAUSEWAY &

188479-400-PI-01-000001
JETTY BUILDINGS
AREA PLOT PLAN - MOF & LNG LOADING RACK &

188479-400-PI-01-000002
CAUSEWAY
188479-400-PI-01-000003 AREA PLOT PLAN - LNG LOADING BERTH 1 (NORTH)
188479-400-PI-01-000004 AREA PLOT PLAN - LNG LOADING BERTH 2 (SOUTH)
188479-500-PI-01-000001 AREA PLOT PLAN - SITE ADMIN & FACILITIES AREA
188479-500-PI-01-000002 AREA PLOT PLAN - TRUCK LOADING AREA
188479-600-PI-01-000001 AREA PLOT PLAN - INLET FACILITIES
188479-600-PI-01-000002 AREA PLOT PLAN - HP FLARE
188479-700-PI-01-000001 AREA PLOT PLAN - UTILITIES AREA
188479-900-PI-01-000001 AREA PLOT PLAN - POWER GENERATION

10.6 ANNEX 4 – CIVIL STRUCTURAL & CONSTRUCTION -
CONFIDENTIAL AND PROPRIETARY
OVERALL SITE PLAN - TEMPORARY FACILITIES &

188479-000-CN-01-000001
LAYDOWN
188479-000-CV-DB-00007 SEISMIC BASIS OF DESIGN

10.7 ANNEX 5 – MARINE -CONFIDENTIAL AND PROPRIETARY
188479-400-MA-BD-00001 JETTY MARINE STRUCTURES - BASIS OF DESIGN
PRELIMINARY MARINE FACILITIES STRUCTURES LNG

188479-410-MA-05-000001
JETTY & MARINE TRESTLE - OVERALL PLAN
188479-440-MA-05-000001 OVERALL PLAN - MOF

10.8 ANNEX 6 – MECHANICAL, HVAC & TANKS - CONFIDENTIAL AND
PROPRIETARY
188479-000-ME-LS-00001 HVAC EQUIPMENT & UTILITY LOAD LIST
CORROSION CONTROL & MATERIAL DESIGN

188479-000-ME-PH-00001
PHILOSOPHY
188479-000-ME-PH-00002 HVAC DESIGN PHILOSOPHY
188479-000-ME-PH-00005 NOISE CONTROL PHILOSOPHY
188479-000-ME-RP-00001 MATERIAL SELECTION REPORT
188479-000-ME-RP-00002 NOISE REPORT
188479-000-ME-SP-00044 PASSIVE FIRE PROTECTION SPECIFICATION
TECHNICAL SPECIFICATION FOR PIPING MATERIAL

188479-000-PI-SP-00005
CLASSES
188479-000-PI-SP-00006 PIPING MATERIAL SPECIFICATION INDEX
188479-300-SP-SP-00001 LNG TANK SPECIFICATION

10.9 ANNEX 7 – ELECTRICAL - CONFIDENTIAL AND PROPRIETARY
188479-000-EL-20-000001 SINGLE LINE DIAGRAM - TRAIN 1 NORTH SUBSTATION
SINGLE LINE DIAGRAM - POWER GENERATION

188479-000-EL-20-000002
BUILDINGS
188479-000-EL-20-000003 SINGLE LINE DIAGRAM - TRAIN 1 SOUTH SUBSTATION
188479-000-EL-20-000006 SINGLE LINE DIAGRAM - UTILITY & JETTY SUBSTATIONS
188479-000-EL-20-000007 SINGLE LINE DIAGRAM - BOG SUBSTATION
SINGLE LINE DIAGRAM - GROUNDING - POWER

188479-000-EL-20-000020
GENERATION
SINGLE LINE DIAGRAM - GROUNDING - TYPICAL

188479-000-EL-20-000021
SUBSTATION
SINGLE LINE DIAGRAM - GROUNDING - EXTERNAL

188479-000-EL-20-000022
AREAS
188479-000-EL-20-000510 SINGLE LINE DIAGRAM - AC UPS
188479-000-EL-20-000520 SINGLE LINE DIAGRAM - DC TRIP CLOSE UPS
188479-000-EL-31-000001 ELECTRICAL BLOCK DIAGRAM - IEC 61850 NETWORK
188479-000-EL-31-000050 ELECTRICAL BLOCK DIAGRAM - NORMAL LIGHTING
188479-000-EL-31-000060 ELECTRICAL BLOCK DIAGRAM - EMERGENCY LIGHTING
188479-000-EL-LS-00001 ELECTRICAL EQUIPMENT LIST
188479-000-EL-LS-00002 ELECTRICAL LOAD SCHEDULE NORMAL AND ESSENTIAL
188479-000-EL-LS-00003 ELECTRICAL LOAD SCHEDULE UPS (AC & DC)
188479-000-EL-PH-00001 ELECTRICAL DESIGN PHILOSOPHY

AREA CLASSIFICATION PLAN - AREA 100 - LNG PROCESS
188479-100-EL-10-000001
TRAIN 1
AREA CLASSIFICATION PLAN - AREA 200 - LNG PROCESS

188479-200-EL-10-000001
TRAIN 2
AREA CLASSIFICATION PLAN - AREA 300 - LNG STORAGE

188479-300-EL-10-000001
TANKS
AREA CLASSIFICATION PLAN - AREA 300 - STORAGE

188479-300-EL-10-000002
AREA REFRIGERANT
AREA CLASSIFICATION PLAN - AREA 300 - BOG

188479-300-EL-10-000003 COMPRESSORS, LP FLARE & GAS CONDENSATE
STORAGE
AREA CLASSIFICATION PLAN - AREA 400 - LNG LOADING

188479-400-EL-10-000001
RACK, CAUSEWAY & JETTY BUILDINGS
AREA CLASSIFICATION PLAN - AREA 400 - MOF & LNG

188479-400-EL-10-000002
LOADING RACK & CAUSEWAY

188479-400-EL-10-000003
BERTH 1 NORTH

188479-400-EL-10-000004
BERTH 2 SOURTH
AREA CLASSIFICATION PLAN - AREA 500 - SITE ADMIN &

188479-500-EL-10-000001
FACILITIES AREA
AREA CLASSIFICATION PLAN - AREA 500 - TRUCK

188479-500-EL-10-000002
LOADING AREA
AREA CLASSIFICATION PLAN - AREA 600 - INLET

188479-600-EL-10-000001
FACILITIES
188479-600-EL-10-000002 AREA CLASSIFICATION PLAN - AREA 600 - HP FLARE
188479-700-EL-10-000001 AREA CLASSIFICATION PLAN - AREA 700 - UTILITY AREA
AREA CLASSIFICATION PLAN - AREA 900 - POWER

188479-900-EL-10-000001
GENERATION

10.10 ANNEX 8 – INSTRUMENTS & TELECOMS - CONFIDENTIAL AND
PROPRIETARY
INTEGRATED CONTROL AND SAFETY SYSTEM BLOCK

188479-000-IC-07-000001
DIAGRAM - SHEET 1 OF 3

188479-000-IC-07-000002

188479-000-IC-07-000003
CONDITION & PERFORMANCE MONITORING SYSTEM

188479-000-IC-07-000007
BLOCK DIAGRAM
188479-000-IC-07-000008 METERING SYSTEM BLOCK DIAGRAM
BERTHING MOORING ENVIRONMENTAL MONITORING

188479-000-IC-07-000009
SYSTEM BLOCK DIAGRAM
188479-000-IC-07-000010 TANK GAUGING SYSTEM BLOCK DIAGRAM
FIBRE OPTIC LEAK DETECTION OVERALL BLOCK

188479-000-IC-07-000011
DIAGRAM
188479-000-IC-DB-00001 INSTRUMENTATION BASIS OF DESIGN
188479-000-IC-LS-00001 FIRE AND GAS INDEX
INSTRUMENTATION AND CONTROL SYSTEM

188479-000-IC-PH-00001
PHILOSOPHY
188479-000-IC-PH-00003 METERING PHILOSOPHY
188479-000-IC-SP-00001 ALARM MANAGEMENT SPECIFICATION
BERTH MOORING AND ENVIRONMENTAL MONITORING

188479-000-IC-SP-00002
SYSTEM SPECIFICATION
CONTINUOUS EMISSIONS MONITORING SYSTEM

188479-000-IC-SP-00003
SPECIFICATION
INTEGRATED CONTROL AND SAFETY SYSTEM (ICSS)

188479-000-IC-SP-00005
SPECIFICATION

OVERALL TELECOMMUNICATIONS SYSTEM BLOCK
188479-000-TE-04-000001-01
DIAGRAM
188479-000-TE-04-000002-01 FIBRE OPTIC SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000003-01 STRUCTURED CABLING SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000004-01 SECURITY NETWORK SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000005-01 CORPORATE NETWORK SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000006-01 TELEPHONE SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000007-01 PAGA SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000008-01 RADIO SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000009-01 MARINE SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000010-01 SECURITY CCTV SYSTEM BLOCK DIAGRAM
188479-000-TE-04-000011-01 PROCESS CCTV SYSTEM BLOCK DIAGRAM
PERIMETER INTRUSION DETECTION SYSTEM BLOCK

188479-000-TE-04-000013-01
DIAGRAM
NETWORK MANAGEMENT SYSTEM SYSTEM BLOCK

188479-000-TE-04-000014-01
DIAGRAM
TELECOMMUNICATION AND SECURITY SYSTEM

188479-000-TE-PH-00001
PHILOSOPHY

10.11 ANNEX 9 – SAFETY & ENVIRONMENTAL CONFIDENTIAL AND
PROPRIETARY
188479-000-PI-01-000004 AIR EMISSION LOCATION PLAN - LNGC & O&U
188479-000-PI-01-000005 AIR EMISSION LOCATION PLAN JETTY & BERTHS
P&ID UNIT 79 FIRE PROTECTION - FRESHWATER

188479-000-SE-01-079001
FIREWATER PUMPS
P&ID UNIT 79 FIRE PROTECTION - FRESHWATER

188479-000-SE-01-079002
FIREWATER JOCKEY PUMPS
P&ID UNIT 79 FIRE PROTECTION - SEAWATER

188479-000-SE-01-079003
FIREWATER PUMPS
P&ID UNIT 79 FIRE PROTECTION - FIREWATER UTILITIES

188479-000-SE-01-079004
SITE ADMIN AND FACILITIES AREA
P&ID UNIT 79 FIRE PROTECTION - FIREWATER LNG

188479-000-SE-01-079005
PROCESS AREA 1
P&ID UNIT 79 FIRE PROTECTION - FIREWATER INLET
188479-000-SE-01-079007
FACILITIES
P&ID UNIT 79 FIRE PROTECTION - FIREWATER TRUCK
188479-000-SE-01-079008
LOADING BOG COMP/CONDENSATE AREA
P&ID UNIT 79 FIRE PROTECTION - FIREWATER LNG AND

188479-000-SE-01-079009
REFRIGERANT STORAGE AREA
P&ID UNIT 79 FIRE PROTECTION - FIREWATER JETTY

188479-000-SE-01-079010
AND LOADING BERTHS
P&ID UNIT 79 FIRE PROTECTION - TYPICAL FIREWATER

188479-000-SE-01-079011
EQUIPMENT DETAILS
P&ID UNIT 79 FIRE PROTECTION - JETTY & LOADING

188479-000-SE-01-079012
BERTHS TYPICAL FIREWATER DETAILS
P&ID UNIT 79 FIRE PROTECTION - FIREWATER POWER

188479-000-SE-01-079013
GENERATION
UTILITY FLOW DIAGRAM - UNIT 79 FIREWATER -

188479-000-SE-04-079001
COMMON
188479-000-SE-04-079002 UTILITY FLOW DIAGRAM - UNIT 79 FIREWATER - JETTY
188479-000-SE-DB-00001 FIRE & GAS, SPILL DETECTION BASIS OF DESIGN
LNG SPILL CONTAINMENT/IMPOUNDMENT BASIS OF

188479-000-SE-DB-00002
DESIGN

188479-000-SE-DB-00003 ENVIRONMENTAL DESIGN BASIS
188479-000-SE-DB-00004 FIRE PROTECTION BASIS OF DESIGN
188479-000-SE-LS-00001 AIR EMISSIONS SUMMARY
188479-000-SE-LS-00003 HAZARDOUS AREA CLASSIFICATION - SCHEDULE
188479-000-SE-LS-00004 PASSIVE FIRE PROTECTION (PFP) - SCHEDULE
188479-000-SE-LS-00005 SAFETY/ENVIRONMENTAL EQUIPMENT LIST
188479-000-SE-LS-00007 EFFLUENTS AND WASTE SUMMARY
188479-000-SE-PH-00001 DESIGN SEE PHILOSOPHY
188479-000-SE-PH-00003 EMERGENCY RESPONSE PHILOSOPHY
EMISSIONS AND AIR QUALITY MANAGEMENT

188479-000-SE-PH-00004
PHILOSOPHY
188479-000-SE-PH-00005 ENVIRONMENTAL MANAGEMENT PHILOSOPHY
188479-000-SE-PH-00006 SPILL PREVENTION AND RESPONSE PHILOSOPHY
188479-000-SE-PH-00007 SURFACE WATER MONITORING PHILOSOPHY
188479-000-SE-PH-00008 WASTEWATER MANAGEMENT PHILOSOPHY
188479-000-SE-PH-00009 ESCAPE / EVACUATION & RESCUE PHILOSOPHY
188479-000-SE-RP-00001 HAZOP REPORT
188479-000-SE-RP-00003 EXPLOSION ASSESSMENT
188479-000-SE-RP-00004 FIREWATER DEMAND REPORT
188479-000-SE-RP-00006 SUPPLEMENTARY HAZID/ENVID STUDY REPORT

188479-000-SE-RP-00008 HAZID/ENVID STUDY REPORT
PRELIMINARY RADIATION, GAS DISPERSION, EXPLOSION

188479-000-SE-RP-00012
AND FIRE MODELLING REPORT
188479-000-SE-RP-00013 QUANTITATIVE RISK ANALYSIS (QRA)
188479-000-SE-RP-00015 SIL ASSESSMENT REVIEW
188479-000-SE-SP-00001 SPECIFICATION FOR FIREWATER DEVICES
FIRE & GAS DETECTION LAYOUT - LNG PROCESS

188479-100-SE-02-000011
TRAIN.1
188479-300-SE-02-000011 FIRE & GAS DETECTION LAYOUT - LNG STORAGE TANKS
FIRE & GAS DETECTION LAYOUT - REFRIGERANT

188479-300-SE-02-000012
STORAGE
FIRE & GAS DETECTION LAYOUT - GAS CONDENSATE

188479-300-SE-02-000013
STORAGE
FIRE & GAS DETECTION LAYOUT - LNG LOADING RACK

188479-400-SE-02-000011
CAUSEWAY AND JETTY BUILDINGS
FIRE & GAS DETECTION LAYOUT - LNG LOADING RACK

188479-400-SE-02-000012
CAUSEWAY
FIRE & GAS DETECTION LAYOUT - LNG LOADING BERTH

188479-400-SE-02-000013
1 (NORTH)
FIRE & GAS DETECTION LAYOUT - LNG LOADING BERTH

188479-400-SE-02-000014
2 (SOUTH)
FIRE & GAS DETECTION LAYOUT - SITE ADMIN &

188479-500-SE-02-000011
FACILITIES AREA
FIRE & GAS DETECTION LAYOUT - TRUCK LOADING

188479-500-SE-02-000012
AREA
188479-600-SE-02-000011 FIRE & GAS DETECTION LAYOUT - INLET FACILITIES
188479-600-SE-02-000012 FIRE & GAS DETECTION LAYOUT - HP FLARE AREA
188479-700-SE-02-000011 FIRE & GAS DETECTION LAYOUT - UTILITIES AREA

188479-900-SE-02-000011 FIRE & GAS DETECTION LAYOUT - POWER GENERATION

10.12 ANNEX 10 – COMMISSIONING - CONFIDENTIAL AND
PROPRIETARY
188479-000-CM-PH-00001 MAINTENANCE PHILOSOPHY
188479-000-CM-PH-00002 OPERATIONS PHILOSOPHY
PRECOMMISSIONING AND COMMISSIONING

188479-000-CM-PH-00003
PHILOSOPHY
188479-000-CM-PH-00004 SPARES PHILOSOPHY
188479-000-CM-PH-00006 BLACK START PHILOSOPHY

10.13 ANNEX 11 – WATER SUPPLY PIPELINE - CONFIDENTIAL AND
PROPRIETARY
RAW WATER SUPPLY PIPELINE – HYDROLOGIC

14-1170-HR-0.0
ASSESSMENT REPORT
14-1170-EI-1.0 EXISTING INFRASTRUCTURE REPORT
14-1170-PR-1.0 PIPELINE ROUTING REPORT
14-1170-DESBREF-1.0 DESIGN BRIEF
DRAWINGS FOLDER

ANNEX P – PUBLIC DOCUMENTS
188479-000-PI-01-000001 OVERALL SITE PLAN - LNGC-O&U-JETTY
188479-000-PI-01-000002 OVERALL PLOT PLAN - LNGC & O&U
188479-000-PI-01-000003 OVERALL PLOT PLAN - JETTY & BERTH
188479-000-PR-05-000001 OVERALL BLOCK FLOW DIAGRAM

TRUE
NORTH PLANT
NORTH
37
SA
BL
EG
AS
PL
AN
T
LNGC - O&U
PLANT
AIR
At l a n t i c O c e a n
Atl antic Ocean
At l ant ic Ocean
100 250 500m
A B C D E F G H I J
INLET GAS RAW WATER EMERGENCY ENTRY / EXIT

PIPELINE PIPELINE
DRAWING LIMIT
H
1 FENCE LINE / SITE BOUNDARY GATE
41.0m
INLET GAS
FACITILIES
H
38.0m
52.1m
HAUL ROAD
2 RAW WATER
TANK H
HEATING
ANALYSER MEDIUM TANK
HOUSE
SOLVENT
HP FLARE TANK
FLARE
MAX RADIA
TION LEVEL KO DRUMS SUB STN POWER GENERATION
3 KW/M2 AREA
LER 4
DARY
AREA m
STE RILE IGHT 170
00m K HE
BOUN
2 AC
2 - ST
5kw/m
ROAD
ITE
3
E/ S
E
E LIN
HAUL ROAD
SABL
FUEL GAS
FE N C
OXIDISER
OXIDISER
THERMAL
THERMAL
RY
ORRIDOR
SITE BOUNDA
H 52.1m R15 SUB STN R15 SUB STN
NGL EXTRACTION
ACID GAS REMOVAL
ACID GAS REMOVAL
NGL EXTRACTION
LINE C
FENCE LINE /
EXISTING PIPE
4
SECURITY GATE
FRESH/FIRE
WATER DEMIN H
CAR WATER
FIRE &
PROCESS COMPRESSORS
PARK CAR CAR CONTROL
MAIN SITE
REFRIGERATION
MEDICAL
REFRIGERATION
PARK PARK BUILDING
ENTRANCE
PROCESS COMPRESSORS
POTABLE
HAUL ROAD
GATE
WATER
WORKSHOP
23.5m
DRAWING LIMIT
38.0m CAR ADMIN SUB STN
PARK CENTRE FRESH WATER
5 GENERATORS TREATMENT
DRAWING LIMIT
H
38.0m 38.0m
23.5m
LIQUEFACTION
LIQUEFACTION
ION ION
PERS PERS
END FLASH GAS

CHEMICAL S DIS S DIS LNG
END FLASH GAS

A A
WAREHOUSE
G G
STORAGE LAYDOWN NITROGEN 160m 160m IMPOUNDING
BASIN
FENCE LINE
AREA
FENCE LINE
100m x 50m
ASDS
ASDS
TRUCK
PARK LER 1 LER 2
SUB STN SUB STN
DARY
SECURITY
N
DIESEL TRAIN 1 TRAIN 2
O
BOUN
SI
CAR SEWAGE STORAGE
R
CAR
PE
PARK PLANT
HEAVY GOODS
IS
PARK AIR LPG EXPORT PIPELINE
SITE
D
ENTRANCE
BATTERY LIMIT AREA
AS
G
GATE GATE LPG EXPORT
7m
PIPELINE
23
(BY OTHERS)
GATE WEIGH BRIDGE
FENCE LINE
ANALYSER
GATE HOUSE LER 3 SUB STATION HOUSE FUTURE GAS
& LOCAL CONTROL TRUCK LOADING AREA CONDENSATE
FENCE LINE
BUILDING TRUCK
EXPORT PIPELINE
CAR PARK WAITING
AREA GAS LNG LNG
CONDENSATE STORAGE LNG STORAGE FUTURE
7 STORAGE AREA IMPOUNDING
TANK TANK
NOTE 4 BASIN
FENC REV DATE DESCRIPTION DRN CHK APP CLT
E LIN FUTURE LNG
LOCAL ADMIN
& SALES BUILDING
E/ S
ITE
BOU
NDA
IMPOUNDING 23.5m
RY BASIN
EMERGENCY
ENTRY / EXIT
N
SITE
O EMERGENCY EXIT
SI
P ER GATE HOUSE
BOUN
IS
D
AS 15.2m REFRIGERANT GATE ACCESS ROAD
DARY
2m
G
FENCE LINE 15.2m STORAGE AREA
12 BOG
COMPRESSOR SITE ACCESS FOR
8 REFRIGERENT SUPPLY
HOUSE
CLEAN SURFACE ROAD TANKERS GOLDBORO LNG PROJECT
H ETP
WATER POND
FUTURE
DUNG COVE
15.2m
HAUL R
OAD
CULVERT UNDER
HAUL ROAD
OPERATIONAL FENCE
LINE
ROAD
AD
E
IN
TITLE:
RO
EL
50 DIU
RA
9
m S
NC
UL
CLEAN WATER
FE
OUTFALL
HA
SHORE LINE
TE
GA
LP FLARE
12.2m Atlantic Ocean SCALE (A1):
R IDOCS FOLDER:
JETTY SECURITY CA RK
CUSTOMS OFFICE PA
WAREHOUSE GA
TE CONTRACT No:
10
CLIENT CONTRACT No:
MATCHLINE N 2085.000 CONT ON DRAWING No 188479-PI-01-000003
0 20 40 60 80 100 200m DRAWING No. REV
METRES - 1:2500
H
THIS DOCUMENT IS THE PROPERTY OF CHICAGO BRIDGE & IRON COMPANY (CB&). IT MAY CONTAIN INFORMATION DESCRIBING TECHNOLOGY OWNED BY CB& AND DEEMED TO BE COMMERCIALLY SENSITIVE. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY CB&.
REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY CB& IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF CB&. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY.
TRUE
NORTH PLANT
JETTY NORTH
NORTH
37 23
A t l a n t i c O c e a n
E 12-04-16 ISSUED FOR FEED AB JL EM
D 24-02-16 ISSUED FOR FEED
C 20-10-15 ISSUED FOR FEED
B 07-08-15 ISSUED FOR REVIEW
A 04-07-14 ISSUED FOR REVIEW
SECTION ON X - X
0 25 50 75 100 125 250m
THIS DOCUMENT IS THE PROPERTY OF CHICAGO BRIDGE & IRON COMPANY (CB&I). IT MAY CONTAIN INFORMATION DESCRIBING TECHNOLOGY OWNED BY CB&I AND DEEMED TO BE COMMERCIALLY SENSITIVE. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY CB&I .
REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY CB&I IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF CB&I . IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY.
A B C D E F G H I J
NOTES
1. DELETED.
2. REFER TO OVERALL HEAT AND MATERIAL BALANCE
188479-000-PR-LS-00002 FOR STREAM INFORMATION.
1
ACID GAS TO
THERMAL OXIDISER TO FUEL GAS
TO FUEL GAS LNG TRAIN 1

9 13
2
15
FEED GAS INLET MERCURY ACID GAS NGL LIQUEFACTION &

1
FACILITIES REMOVAL
2
REMOVAL
4 DEHYDRATION 5
EXTRACTION
6
REFRIGERATION
7
FROM M&NP
3
10 11
ACID GAS TO
THERMAL OXIDISER TO FUEL
GAS
TO FUEL GAS
LNG TRAIN 2
ACID GAS NGL LIQUEFACTION &

REMOVAL DEHYDRATION EXTRACTION REFRIGERATION
TO FUEL
UTILITIES GAS
PLANT /
6 HEATING
INSTRUMENT NITROGEN WATER FIREWATER
MEDIUM
AIR
ETHYLENE PROPANE
REFRIGERANT REFRIGERANT
STORAGE STORAGE
SAS/
C 15-03-16 ISSUED FOR FEED KW SAS
RB
B 01-02-16 ISSUED FOR CLIENT REVIEW IE SAS SAS

DRAINAGE
POWER FUEL
FLARE DIESEL & EFFLUENT A 16-05-14 IFR SAS DBC DBC
7 GENERATION GAS
TREATMENT
REV DATE DESCRIPTION DRN CHK APP CLT
CONDENSATE & LPG LNG

14
STORAGE & LOADING STORAGE & LOADING
8
12 8 GOLDBORO LNG PROJECT
FILENAME: H:\DEPT\PROCESS\PROCESS CAD\GOLDBORO LNG\PFD\ARCHIVE C\188479-000-PR-05-000001_C.DWG

LNG PRODUCT
CONDENSATE
PRODUCT
TITLE:
9
OVERALL BLOCK FLOW DIAGRAM
SCALE (A1): NTS
IDOCS FOLDER: 14.1.1
CONTRACT No: 188479
10
CLIENT CONTRACT No:
DRAWING No. REV
188479-000-PR-05-000001 C
THIS DOCUMENT IS THE PROPERTY OF CHICAGO BRIDGE & IRON COMPANY (CB&I). IT MAY CONTAIN INFORMATION DESCRIBING TECHNOLOGY OWNED BY CB&I AND DEEMED TO BE COMMERCIALLY SENSITIVE. IT IS TO BE USED ONLY IN CONNECTION WITH WORK PERFORMED BY CB&I.
REPRODUCTION IN WHOLE OR IN PART FOR ANY PURPOSE OTHER THAN WORK PERFORMED BY CB&I IS FORBIDDEN EXCEPT BY EXPRESS WRITTEN PERMISSION OF CB&I. IT IS TO BE SAFEGUARDED AGAINST BOTH DELIBERATE AND INADVERTENT DISCLOSURE TO ANY THIRD PARTY.

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APPLICATION TO

NOVA SCOTIA UTILITIES AND REVIEW

2 GAS PLANT FACILITY REGULATIONS AND THE CODE OF PRACTICE ............................. 3

3 PROCESS SAFETY MANAGEMENT ........................................................................................ 3

6 SEISMIC REVIEW .................................................................................................................... 35

7 PRELIMINARY HAZARD AND OPERABILITY STUDY (HAZOP) .......................................... 37

8 FACILITY SITING AND LAYOUT ANALYSIS ......................................................................... 37

9 PRELIMINARY FACILITY AND SECURITY ASSESSMENT .................................................. 39

Goldboro LNG: Application for a Permit to Construct 2

1.2 THE PROJECT

The following is a 3D rendering of the Facility.

Goldboro LNG: Application for a Permit to Construct 1

1.4 BENEFITS TO NOVA SCOTIANS

Goldboro LNG: Application for a Permit to Construct 2

3 PROCESS SAFETY MANAGEMENT

Goldboro LNG: Application for a Permit to Construct 3

3.1.1 TECHNOLOGY INFORMATION FOR PROCESS, UTILITY AND SUPPORT

3.1.1.1 PROCESS CHEMISTRY

Goldboro LNG: Application for a Permit to Construct 4

Information Centre • Pieridae plans to operate an information centre at the site

Goldboro LNG: Application for a Permit to Construct 5

NGL Extraction Unit

Goldboro LNG: Application for a Permit to Construct 6

Propane is stored as an ambient temperature pressurized liquid in 2 x 50% bullets. The

LNG Storage and Loading

Goldboro LNG: Application for a Permit to Construct 7

Goldboro LNG: Application for a Permit to Construct 8

• Jetty loading platforms

The jetty topsides on each loading platform includes:

• Two loading arms

The MOF comprises two distinct components:

Condensate & LPG Storage & Loading

Goldboro LNG: Application for a Permit to Construct 10

Diesel Fuel System

Goldboro LNG: Application for a Permit to Construct 11

• Utility hose stations

Fresh/Potable/Demineralised Water Systems

The Effluent Treatment system comprises of the following elements:

• Clean Surface Water System (CSS)

Goldboro LNG: Application for a Permit to Construct 14

Sanitary waste water will be collected and processed in a Sewage Treatment

• Hazardous Chemical System (HCS)

Goldboro LNG: Application for a Permit to Construct 15

• Oily Water Treatment

• Water Supply Pipeline

Water is obtained from a pumping station installed at Meadow Lake. A study

§ Confirmation of Meadow Lake’s suitability as the water supply source

Details of the above are contained in Annex 11.

Goldboro LNG: Application for a Permit to Construct 16

The following image is a 3D rendering of the Project.

Overall Site Plan – LNGC-O&U-JETTY Document No. 188479-PI-01-000001

Overall Plot Plans – LNGC & O&U Document No. 188479-PI-01-000002

Area Plot Plans

Goldboro LNG: Application for a Permit to Construct 17