Attachment C.l Organisational Chart for Terminal Operation

Contents

Attachment C.l

Attachment C.2

Organisational Chart for Terminal Operation

Shell E&P Ireland Ltd HSE Policy

Attachment C.3 Royal Dutch/Shell Group Procedure for an HSE Management System

. . . ,j .’

_ . : : .‘/,

. ,

: ,’ .:’

..‘. .

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:21

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:21

Shell Group Commitment to Health, Safety and the Environment In the Shell Group we are all committed to: . pursue the goal of no harm to people; a protect the environment; 4 use material and energy efficiently to provide our products and services; I develop energy resources, products and services consistent with these aims; e publicly report on our performance; . play a leading role in promoting best practice in our industries; + manage HSE matters as any other critical business activity; e promote a culture in which all Shell employees share this commitment. In this way we aim to have an HSE performance we can be proud of, to earn the confidence of customers, shareholders and society at large, to be a good neighbour and to contribute to sustainable development.

Shell Group Health, Safety and Environment policy Every Shell Company: - has a systematic approach to HSE management designed to ensure compliance with the law and to achieve

continuous performance improvement; . sets targets for improvement and measures, appraises and reports performance; . requires contractors to manage HSE in line with this policy; - requires joint ventures under its operational control to apply this policy and uses its influence to promote

it in other ventures; . includes HSE performance in the appraisal of all staff and rewards accordingly. Endorsed by the Committee of Managing Directors, March 1997 Reviewed 2000

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:22

Group HSE Management System

The companies belonging to the Royal Dutch/Shell Group of companies are separate and distinct entities, but in this document the collective expressions “Shell” and “Group” are sometimes used for convenience in contexts where reference is made to the companies of the Royal Dutch/Shell Group in general. These expressions are also used where no useful purpose is served by identifying the particular company or companies.

This document is prepared by Shell international B.V. (3) as a service under arrangements in existence with companies of the Royal Dutch/Shell Group; it is issued for the guidance of these companies and they may wish to consider using it in their operations. Other interested parties may receive a copy of this document for their information. SI is not aware of any inaccuracy or omission from this document and no responsibility is accepted by SI or by any person or company concerned with furnishing information or data used in these guidelines, for the accuracy of any information or advise given in the guidelines or for any omission from the guidelines or for any consequences whatsoever resulting directly or indirectly from compliance with or adoption of guidance contained in the guideline even if caused by a failure to exercise reasonable care.

February 2002

HEALTH, SAFETY AND ENVIRONMENT ADVISERS PANEL

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:22

‘, .

.

Appendix 3: Group Pioc&dure for an HSE Management System ‘.

Appendix 3: Group Procedure for an HSE Management System

A systematic approach to HSE management requires the following elements arranged to provide a feedback * loop to achieve continuous improvement in performance. Such a system should be set LIP in a way that can

be externallv certified against an international system stanclard. Minimum requirements uncler each heading are given.

. Demonstrable Management Leadership, Planning, Commitment and Review Management and supervision shall be regarded as being fully committed to HSE by all staff and

contractors. They are to be seen as providing a leading role towards constant improvement through leadership and action planning. Management shall regularly review the suitability and effectiveness of

the system.

. Policy and Strategic Objectives Companies shall each have a written HSE Policy, covering the Group Policy elements as a minimum.

HSE objectives shall be challenging, understood by all and consistently incorporated in policies.

In setting objectives, management shall consider the overall risk levels of its activities and shall identify those critical operations and installations which require a fully documented demonstration that risks

have been reduced to as low as reasonably practicable (ALARP). (See Hazards and Effects Management Process below).

. Organisation and Responsibilities The organisation and resources shall be adequate for its purpose. Responsibilities at all levels shall be

clearly described, communicated and understood. Staff shall be developed following structured competency assessment and training systems.

l Hazards and Effects Management Process

The process for those critical operations and installations shall include:

l An inventory of the major hazards to the environment and to the health and safety of all the activities, materials, products and services;

l An assessment of the related risks, implementation of measures to control these risks and to recover

in case of control failure.

Health risk assessment shall address physical, chemical, biological, ergonomic and psychological health hazards associated with work,

Environmental (impact) assessment (including a consideration of social impacts) shall be conducted prior to all new activities and facility developments, or significant modifications to existing ones.

Soil and groundwater contamination shall be assessed and, where required, control or remediation shall be in-hand.

Product stewardship shall be applied at all stages of product life cycle relevant to the Company’s activities.

. Standards, Procedures and Document Control Adequate standards and procedures shall be in place and understood at the appropriate organisational levels. Preparation, review and distribution of all key reference documentation shall be adequately

controlled.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:22

. t . , .

. . ,

I &5@$ix 3: Group Procedure fhr an HSE Management System

0

Emergency response procedures (including medical emergencies) shall be regularly tested.

. Implementation, Monitoring and Corrective Action HSE performance targets shall be set to ensure progression towards the long term goals of no harm to

people and to protect the environment. Performance indicators shall be established, monitorecl and results reportecl in a way that can be externally verifiecl.

All HSE incidents ancl near-misses with significant actual or potential consequences shall be thoroughly investigated and reported.

l Audit An audit programme shall be in place to review and verify effectiveness of the management system. It

shall include audits by auditors independent of the process or facility audited. Audit follow-up shall be timely, thorough and auditable.

An HSE assessment shall form an integral part of any proposal for acquisition, divestment, abandonment or merger of business entities.

In the case of joint ventures that are not under Shell Companies’ control the business risks that are related to HSE shall be assessed.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:22

Contents

Attachment D.l

Attachment D.2

Attachment D.3

Attachment D.4

Attachment D.5

Attachment D.6

Overall Plot Plan (Drg No. L3847-050-110-1000 Rev. B4) Plot Plan Equipment List (Drg No. L3847-050-110-1000 Rev. Bl)

Simplified Process Flow Diagram of Terminal Operations (Figure 2.2)

Process Control - General

Process Unit Operations l Inlet and Reception Facilities l Gas Conditioning l Gas Compression and Export l Condensate Recovery and Stabilisation l Methanol Recovery, Regeneration and Chemical Injection

Utilities l Fuel Gas System l Heating Medium System l Utility Gases l Potable and Service Water Systems l Power Generation

Safety Systems l Flaring l Firewater l Nitrogen Blanketing

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:22

Placeholder This page has been inserted to indicate that content

has been extracted from this location in the document and has been stored in a separate file.

(Tliis is due to file size issues.)

The extracted content can be found in the following electronic pdf file:

Application Form-Drawing-07

,

”

. ,’ :

‘/

Licence: PO738-0 1

,’

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:22

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:22

: ;., a D.3 Process Control - General

The Terminal facilities are designed to operate ove determined by the production profiles and gas reservoir c or “Sales” gas is exported directly into the BGE distribution pressure. The delivery rate of gas, fiscally measured, from t controlled according to daily nominations from the customer(s).

The whole Corrib Field Development (onshore and offshore) will be controlled from the onshore Terminal control room. A Control System will control the onshore facilities and an Electra-Hydraulic system will control the offshore facilities. Based upon a manning philosophy that is sufficient for safe operation, the Terminal control room will provide all the necessary information to safely control the offshore facility, gas and liquid processing at the onshore Terminal and gas export to the national grid. The control system will provide for the continuous processing and production requirements of the facility on a 24 hour, 365 day per year basis.

The control system will allow the control room operators to view all the necessary process variables and make appropriate adjustments as required. In the event of process upsets and/or hazards, manual or automatic predetermined sequences will bring the Terminal to a safe state, ranging from unit shutdowns to total plant shutdown.

Programmable Logical Controllers (PLC) / Remote Terminal Units (RTU) for the control system field interface hardware will be mounted in the local equipment room (LER l), located in the field adjacent to the process area to minimise buildings and field cabling. The Corrib Field offshore (sub-sea) facilities will be controlled and monitored via an electro-hydraulic remote control system. Electrical power, control and data signals, along with hydraulic control and chemical injection fluids will be carried in an underwater umbilical cable buried in the seabed.

The overall availability of the control system will be commensurate with continuous operation and will provide facilities for on-line maintenance without loss of control or display features. To this effect the system will have inherent module and component redundancy with diagnostic features that will allow rapid and detailed fault recognition to module level.

Safety systems will be provided which are intentionally separate from the control system in terms of separate field instrumentation and separate system electronics. The systems provided will recognise predicted hazards and have pre-configured logic sequences that will bring the Corrib facility to a safe state regardless of operator action. Additionally, operator initiated shutdowns shall be provided to initiate the predetermined shutdown logic sequences should an impending hazard be recognised by the operator. The Emergency Shutdown (ESD) system at the Terminal will ensure the safe isolation and shutdown of equipment under fault or fire conditions and will provide a basis for the safe and efficient shutdown of process operations and the isolation of flammable / toxic materials within the facilities. Emergency shutdown (ESD) and isolation will be initiated by fire and/or gas detection or by process deviations.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

’

D.4 h-ocess Unit Operations This section includes process descriptions and simplified process flow diagrams (PFDs) for the main process unit operations at the Terminal. For ease of reference, in the process descriptions, the main equipment is numbered in accordance with the Overall Plot Plan included as Attachment D. 1.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

: t, : :; ..,,: ..y. .: ‘, ;,; e .) D.4.1 Inlet and Reception Facilities (Gas Reception and Primary Separation)

Purpose The purpose of the Inlet and Reception Facilities is to receive the gas from the Corrib Field and remove the entrained water and liquid hydrocarbons. The fluids from the Corrib Gas Field that are received at the Terminal will be mainly gas, but some liquid will also be present. Gas (and production fluids) will arrive at the Terminal, generally as a very fine mist, but the liquids will not arrive at the Terminal in a uniform manner. The liquids in the pipeline will tend to run back along the pipe particularly at times of low gas flow and will collect at low-points, or dips, in the pipeline. As liquid builds up at these low points, it will be picked up by the fast-flowing gas and will arrive in varying quantities, or ‘slugs’.

The liquids consist primarily of:

l

Water phase: l Water: Water of Condensation (present in the gaseous form within the Corrib

Field and condenses out from the gas as it’s temperature and pressure fall) and Formation Water (present in the liquid form within the reservoir which, if it occurs, it is only expected later in the field life)

l Methanol (injected from the Terminal to prevent freezing in the subsea equipment and pipeline).

l Corrosion/scale inhibitor (chemicals injected into the subsea system to prevent corrosion and the precipitation of minerals (scale)).

Liquid Hydrocarbon phase: l Condensate (liquid hydrocarbons that condense from the gas as its temperature

and pressure fall)

Process Description If required, build-up of liquids in the pipeline are cleared by running a sphere (known as a pig) through the line. A Pig Receiver (D-1001) receives pigs launched off-shore and a Pig Launcher (D2003) launches pigs from the Terminal.

During normal operation the production fluids enter the Terminal at a pressure of up to 13 5 barg and a temperature of between 2 and 15 “C, dependent on subsea wellhead conditions, gas rate and ambient conditions.

The pipeline fluids enter the Slugcatcher (D-1002) where the liquid phases (aqueous and hydrocarbon) are removed. The Slugcatcher is a finger type design, made up of 8 x 24 inch (diameter) fingers of 92m length each. Primary separation is achieved by slowing the velocity sufficiently to allow liquids to drop out of the gas phase. The hydrocarbon and aqueous phases are removed under level control to the condensate recovery and methanol regeneration systems respectively.

Gas exits the Slugcatcher and, in normal operation, bypasses the Inlet Heater (E- 1002). The Inlet Heater is only used during plant start-up when unpacking the pipeline to avoid the occurrence of excessively low temperatures downstream of the inlet pressure control valve. The Inlet Heater is a shell and tube exchanger, using the

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

a

heating medium (Triethylene Glycol (TEG)/water), to raise the gas temperature to 12°C. The gas is then pressure controlled to 106 barg, and passed to the Inlet Filter Separator (D-1003).

The Inlet Filter Separator (D-1003) provides secondary separation of the gas from any carryover condensate and water. The aqueous phase is discharged under level control to the Methanol Flash Drum (D-4001) with the condensate layer being level controlled into the MP Flash Drum (D-3001). The separator contains a demister at the gas outlet nozzle to ensure that the liquid carry-over in the final gas stream is minimised. The gas then flows to gas conditioning.

A simplified Process Flow Diagram (PFD No. 1) of the process is attached.

Process Control Gas flowrate and pressure through the slugcatcher and up to the pressure control valve (PCV) are controlled via chokes located at the well head which are operated from the Terminal control room. Liquid phase hydrocarbon and aqueous methanol streams are discharged from the slugcatcher under level control.

Environmental Emissions

Air Main: Minor:

Potential:

There are no main emissions to air There are normally no minor emissions to air. Maintenance activities may require depressurisation of the plant using the Maintenance Flare (used on a limited infrequent basis). There may be some fugitive hydrocarbon emissions during normal operation. Emergency situations may require depressurisation of the plant using the HP and LP Flares.

Water There are no direct emissions to surface waters / ground waters from this process unit operation. Aqueous methanol streams removed from the gas stream (including Produced Water) are routed to the Methanol Recovery System and ultimately treated in the Produced Water Treated System. Operational and maintenance drainage from the Process areas is collected via a dedicated closed drain collection network and routed to the Closed Drains Drum (D-8201) for either off-site disposal or recovery to process (Refer to Sections E.2 and F.1.2 of the IPPC Application Form for a description of the Produced Water Treatment system and the Closed Drains system).

Waste There is no waste generated from this operation other than from normal maintenance activities.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

PRd%JCilON FLUIDS FROM CORRIB FIELD

Pig Receiver D-1001

NORMALLY BY-PASS

1 Slugcatcher - Aqueous

D-l 002 Hydrocarbon

METHANOL ‘RECOVERY (PFD No.!?)

.CONDENSATE STABILISATION (PFD No.4)

Inlet Heater 4 E-l 002

b

Feed

7 HEATING

p Return MEDIUM (PFD No.7)

v

Inlet Pressure Control Valve

f

GAS CONDITIONING

(PFD No.2) Notes 1. Inlet Heater is used on start-up only

PFD No. 1 - Gas Reception and Primary Separation

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

D.4.2 Gas Conditioning

Purpose The Corrib gas can be considered a very pure gas and therefore the conditioning required to meet the BGE export gas specification is very simple. The purpose of the gas conditioning is to remove any trace mercury (if present), to dry the gas stream (by lowering the dew-point) and to remove any residual hydrocarbon.

Process Description Gas from the Inlet Filter Separator passes to the Feed Gas Mercury Removal Bed (N- 1001). The mercury removal absorbent bed contains a mixture of copper, zinc and aluminium sulphides/oxides. Mercury is removed from the gas stream by a process of oxidation as it comes into contact with the absorbent bed.

The treated gas stream (<10ng/Nm3 mercury) then flows to the Gas/Gas Exchanger (shell and tube unit) (E-2004), where it cross-exchanges with the chilled gas from the Cold Separator (D-2007) which cools the treated gas stream. The Gas/Gas Exchanger may be bypassed until Year 2 operation, when the chilling effect of the Exchanger is required to augment the J-T cooling in ensuring the gas specification is met.

The gas is then expanded in a controlled manner through a valve called a Joule- Thompson (J-T) valve (duty/standby) to give the desired dew point. Aqueous and hydrocarbon liquids are condensed and transferred from the gas phase to liquid phase and thus conditioning / drying of the gas occurs. Hydrate formation across the J-T valve is prevented by methanol injection.

The two-phase fluid from the gas conditioning then passes directly into the Cold Separator (D-2007), where the liquids formed by cooling are separated. The aqueous phase is retained and discharged under level control to the methanol recovery system. Condensate is transferred under level control to the condensate stabilisation system.

Conditioned gas then flows, via the Gas/Gas Exchanger, to the Gas Compression and Export process operation.

A simplified Process Flow Diagram (PFD No.2) of the gas conditioning process is attached.

Process Control Gas pressure and temperature are controlled via the Terminal control system by the J- T valve settings in the Control Room. The gas is temperature controlled to a set-point to meet the gas quality specification. The pressure controller is reset by a temperature controller, which acts to maintain a controlled gas temperature downstream of the J-T valve to achieve a constant gas quality. The efficacy of the mercury removal bed is confirmed by manual sampling on a regular basis.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23


Air Main: Minor:

Potential:

There are no main emissions to air There are normally no minor emissions to air. Maintenance activities may require depressurisation of the plant using the Maintenance Flare (used on a limited infrequent basis). There may be some fugitive hydrocarbon emissions during normal operation. Emergency situations may require depressurisation of the plant using the HP and LP Flares.

Water There are no direct emissions to surface waters / ground waters from this process unit operation. Aqueous methanol streams removed fi-om the gas stream (including Produced Water) are routed to the Methanol Recovery System and ultimately treated in the Produced Water Treated System. Operational and maintenance drainage from the process areas is collected via a dedicated closed drain collection network and routed to the Closed Drains Drum (D-8201) for either off-site disposal or recovery to process (Refer to Sections E.2 and F. 1.2 of the IPPC Application Form for further information on the Produced Water Treatment system and the Closed Drains system).

Waste Absorbent fi-om the mercury removal bed will be periodically replaced and transported off-site for treatment/disposal. Refer to Tables H. 1 (i) and H. 1 (ii) of the IPPC Application Form for details on the waste quantities generated.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

Note 1

FROM INLET FILTER SEPARATOR

(PFD, No.1)

1 Mercury

Removal Bed N-1001

I I

Note 2 , FUEL GAS SYSTEM (PFD No.6)

Gas/&as b Exch,ang& 4 b SALES GAS COMPRESSOR

E3004 ( PFD No.3) \ I I

I

Condensate $- CONDENSATE Cold Separator ’ STABILISATION (PFD No.4)

D-2007 Aqueous b METHANOL RECOVERY

(PFD No.5)

Notes

1. Chilled Gas from Cold Separator to Gas-Gas Exchanger not required until Year 2 Operation

2. During plant start-up only gas may be taken from this point to supply the fuel gas system

PFD No.2 - Gas Conditioning

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

D.4.3 Gas Compression and Export

Purpose Gas is compressed to export pressure, fiscally metered, and odorised for leak detection purposes prior to export to the Bord Gais Eireann (BGE) national distribution system.

Process Description Prior to the Sales Gas Compressors the gas stream passes through a Suction Knockout (KO) Drum (D2009 A/B). The KO drum is similar to a filter and prevents any residual liquid in the gas stream from entering the compressors. The conditioned gas is compressed to export pressure by the Sales Gas Compressors (K-2002 A/B). Two compression trains (compressors), operating on a duty/standby basis are provided with each compressor rated for 100% flow of 350 MMSCFD (million standard cubic feet per day) of natural gas. Each compressor is powered by a gas turbine fuelled from the High Pressure (HP) fuel gas supply.

The gas turbines will operate in simple cycle without waste heat recovery each having a dedicated exhaust stack. The turbines will incorporate low NO, burners. Each turbine has a rating / duty of 7.7 MW and a maximum net rated thermal input of 25.7 MW. Each gas turbine consists of three basic sections: an air compressor section in which air is compressed in a compressor, the combustor section in which fuel (gas) is mixed with the compressed air and burned, and the turbine section where energy is extracted from the hot gases. The expansion of the gases against the blades of the turbine provide power to drive the directly coupled air compressor and sales gas compressor.

After compression the gas stream is air-cooled to 35 “C in the Sales Gas Compressor Aftercoolers (E-2005A/B). Gas for the fuel gas system will be taken downstream of the Aftercoolers.

Sales Gas flow and quality is then measured in the Sales Gas Metering Package (N- 2001), which consists of 2 x 100% metering runs. Gas quality is measured by on-line gas chromatographs and the data reported to the control system.

Odourant is then added to the sales gas by the Odourisation Package (N-2002). This consists of an odourant storage tank and dosing pumps. The odourant is a mixture of Tertiary Butyl Mercaptan (80%) and Di-Methyl Suphide (20%). The package is specified as ‘zero discharge’ during operation and loading and includes activated carbon (anthracite) filters on both the instrument cabinet and storage tank. Any fugitive emissions of odourant generated during maintenance will neutralised by a hand held spray deodorizer used by the maintenance contractor. Therefore there should not be any malodorous fugitive emissions generated.

A simplified Process Flow Diagram (PFD No.3) of the process is attached.

Process Control Full flow relief set at a pressure of 116 barg is provided for each compression train routed to the HP Flare header. Blowdown of each train (to HP Flare) is by operator

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

initiation. Each compressor is protected by an anti-surge recycle valve, which ensures a minimum flow through the machine to avoid surge. The required gas export rate is set in the control system and the compressor speed varied to achieve this.


Air Emissions Main: Combustion byproducts (NO,, CO, unburnt hydrocarbon and water

vapour) from the gas turbines are discharged via Emission Points A2-1 and A2-2.

Minor: Maintenance activities may require depressurisation of the plant using the Maintenance Flare (used on a limited infrequent basis). Occasional cold venting of natural gas to HP flare stack during the start-up of a compressor following a shut down of the other compressor (typically once every 3 months and a maximum of once per month). A small amount of seal gas (80% nitrogen, 20% natural gas) from one of the sales gas compressors (duty/standby) will be vented on a continuous basis to a local vent.

Potential: There may be some fugitive hydrocarbon emissions during normal operation (there will be no odorous fugitive emissions). Emergency situations may require depressurisation of the plant using the HP and LP flares.

Water Emissions There are no direct emissions to surface waters / ground waters from this process unit operation. Operational and maintenance drainage from process areas is collected via a dedicated closed drain collection network and routed to the Closed Drains Drum (D- 8201) for either off-site disposal or recovery to process (Refer to Section E.2 of the IPPC Application Form for further information on the Closed Drains system).

Waste Activated Carbon (anthracite) on the odourisation package will be periodically replaced and transported off-site for treatment/disposal. Refer to Tables H. 1 (i) and H. 1 (ii) of the IPPC Application Form for details on the waste quantities generated.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

j, :: FRijM c;‘AS

CONDITIONING (PFD No.2)

) $Yy; i ,kEFs A

Combustion Air By-Products

b Sales Gas Compressor Fuel Gas (powered by Gas Turbine)

b K-2002 A/B

Compressor After Coolers E-2005 A/B

BORD GAIS EIREANN (BGE) DISTRIBUTION SYSTEM

PFD No.3 - Gas Compression & Export

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

D.4.4 Condensate Recovery & Stabilisation

Purpose Hydrocarbon condensate recovered from the Corrib Field natural gas is stabilised and used as fuel in the Heating Medium Fired Heater. Gas flashed from the process is used in the LP fuel gas system.

Process Description Condensate from the slugcatcher, and other sources in the process area, is fed under flow control through the HP Condensate Filter (F- 1002) which removes any residual solids from the condensate stream and from there to the MP Flash Drum (D-3001). In the flash drum light hydrocarbons are flashed from the condensate streams for use in the LP fuel gas system. The aqueous phase is separated and transferred, under level control, to the Methanol Flash Drum (D-4001).

The condensate stream is then heated in the Condensate Heater (E-*3001) and flows to the LP Flash Drum (D-3002) where more flashing occurs and the condensate is further stabilised. The low pressure flash gas produced is fed to the suction of the LP Gas Compressors (K-3OOlAB) which compress the gas for use in the LP fuel gas system.

The condensate is then pumped under level control to the Condensate Cooler (E- 3002) where the condensate is air cooled. The temperature control acts to adjust the fan pitch or louvre position to vary the cooling achieved. The condensate then passes through a Mercury Removal Bed (N-3001) to reduce the mercury content (if present) of the condensate to < OSppm wt before flowing to the Condensate Storage Tanks. The mercury removal absorbent bed contains a mixture of copper, zinc and aluminium sulphides/oxides. Mercury is removed from the condensate by a process of oxidation as it comes into contact with the absorbent bed.

There are two Condensate Storage Tanks (T-3001 A/B), an on-line tank is used to collect stabilised condensate whilst the second, or off-line tank, supplies stabilised condensate to the Heating Medium Fired Heater. The storage tanks are used alternatively for collection and supply. The storage tanks have internal floating roofs and are nitrogen blanketed. Provision will be made for the export of any excess condensate in the unlikely event that this is required.

Off-spec condensate is routed to the Off-spec Condensate Tank (T-3002) and is recycled back through the MP Flash Drum and stabilisation process. The off-spec condensate tank is a fixed roof nitrogen blanketed tank.


Process Control Condensate is fed under flow control to the MP Flash Drum (D-3001). The MP flash drum is pressure controlled to approximately 6 barg, thus flashing the light hydrocarbons, and the separated aqueous phase is level controlled to the Methanol Flash Drum (D-4001). The resulting condensate stream is level controlled through to

:

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

the Condensate Heater (E-3001) where it is heated to approximately 120°C. The flow of heating medium is controlled to satisfy the condensate exit temperature.

The heated condensate flows to the LP Flash Drum (D-3002), which operates at approximately 1.5 barg, resulting in flashing of the liquid, stabilising the condensate to an Reid Vapour Pressure (RVP) of 12 psia. The low pressure flash gas produced is fed to the suction of the LP Gas Compressors (K-3001AIB) which compress the gas to 5 barg for use in the LP fuel gas system.

The efficacy of the mercury removal beds is confirmed by manual sampling on a regular basis.

All control points are set and trended in the site control system.


Air Main: Minor:

Potential:

There are no main emissions to air The process is normally operated with no minor emissions. Maintenance activities may require depressurisation of the plant using the Maintenance Flare (used on a limited infrequent basis). Although not anticipated during normal operation, if required pressure control on the LP flash drum can be provided by cold venting to the LP flare stack. There may be some fugitive hydrocarbon emissions from the condensate storage tanks during normal operation. Emergency situations may require depressurisation of the plant using the HP and LP Flares.

Water There are no direct emissions to surface waters / ground waters from this process unit operation. Aqueous methanol streams removed from the gas stream (including Produced Water) are routed to the Methanol Recovery System and ultimately treated in the Produced Water Treated System. Operational and maintenance drainage from the Process areas is collected via a dedicated closed dram collection network and routed to the Closed Drains Drum (D-8201) for either off-site disposal or recovery to process (Refer to Sections E.2 and F. 1.2 of the IPPC Application Form for further information on the Produced Water Treatment system and the Closed Drains system).

Waste Filter cartridges from the condensate filter will be periodically replaced and transported off-site for treatment/disposal. Spent absorbent from the mercury removal bed will be periodically replaced and transported off-site for treatment/disposal. Refer to Tables H.l(i) and H.l(ii) of the IPPC Application Form for details on the waste quantities generated.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

FROM SLUGCATCHER D-l 002

1

HP Condensate Filter F-l 002

1 Spent Cartridge ) WASTE

INLET SEPARATOR 1 METHANOL FLASH -7 D-l 003 DRUM D-4001

COLD CONDENSATE COMPRESSOR SUCTION LA HEATER E-2007 r- K.O. DRUM D-2009 A/B

l @-- Flash Gas MP Flash Drum

, LP FUEL GAS SYSTEM (PFD No.6)

D-3001 Aqueous + METHANOL RECOVERY

(PFD No.5)

HEATING __+ Condensate MEDIUM - (PFD No.7)

Heater E-3001

I + I f Off-Spec Condensate Recycle

LP Flash Drum Flash Gas + LP FUEL GAS SYSTEM D-3002 (PFD No.6)

AJMOSPHERE I E-3002 I

Storage Tank T-3002 Condensate

Storage Tanks T-3001 A/B

, HEATING MEDIUM HEATER (PFD No.7)

’ EXPORT (UNLIKELY TO OCCUR)

PFD No. 4 - Condensate Recovery & Stabilisation

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:23

Ii.4.5 Methanol Recovery, Regeneration and Chemical Injection

Purpose Methanol essentially acts as an antifreeze agent and is used to prevent freezing (hydrate formation) within the off-shore and on-shore facilities. Methanol that is injected to the offshore facilities (via the umbilical cable) is recovered from the production fluids entering the Terminal, and regenerated for re-use. Methanol used in the on-shore facilities is collected in the Closed Drams Drum and regenerated for re- use. Corrosion/scale inhibitor is injected into the methanol system for transfer to the off-shore facilities to prevent corrosion/scale in the off-shore facilities.

Process Description Methanol that is separated from hydrocarbons in the slugcatcher and from other sources in the process area is fed under level control through the Aqueous Filter (F- 1001) which removes any residual solids and from there to the Methanol Flash Drum (D-4001). In the flash drum light hydrocarbons are flashed from the methanol streams for use in the LP fuel gas system. The hydrocarbon phase is separated and transferred, under level control, to the MP Flash Drum (D-3001).

The methanol stream then flows to the Raw Methanol Storage Tanks (T-4001 A/B/C) for additional settling and separation of entrained hydrocarbons. The three tanks are operated in fill, settle and draw mode. The three tanks are internal floating roof nitrogen blanketed tanks.

Methanol solution is then pumped to the Methanol Still (C-4001) via the Still Feed/Bottoms Heat Exchanger (E-4001) which heats the raw methanol stream with the water effluent from the still. A Methanol Coalescer (D-4003) is provided downstream of the exchanger to remove any final trace hydrocarbons. Separation of the methanol and water solution takes place in the Still (column), generating two streams; product (98% methanol) and waste (50 ppmwt methanol).

The column is heated via a Kettle Reboiler (B-4001) operating at 113’C. Vapour product from the column is condensed in a forced draught Air Cooler (the Condenser) and flows to the Methanol Reflux Drum (D-4002). Methanol from the Reflux Drum is pumped back either to the column under flow control or to product storage in tanks (T-4002 A/B) under level control. The two tanks are fixed roof nitrogen blanketed tanks. Product methanol from the storage tanks is pressurised by centrifugal booster pumps, passes through the Export Filters (F4002AIB) (to remove any residual solids) and is then pumped to either the Terminal or the offshore system.

Under normal operation the distilled product (methanol) from the Still is totally condensed and there is no venting of gas to the LP flare stack. Under abnormal operations, such as ingression of condensate or non-condensables into the column, cold venting to the LP flare stack may occur.

Corrosion/scale inhibitor is injected into the methanol stream downstream of the Export Filters. The Corrosion/scale Inhibitor Package (N-9001) stores and injects inhibitor into the methanol system for transfer to the offshore facilities.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24


Process Control The methanol still consists of 35 trays and a bottom tray as feed to the reboiler (heating element). The feed-stream enters at the 18th tray fi-om the top of the column. Heat input to the column is achieved via the kettle reboiler utilising the heating medium.

Methanol from the Reflux Drum is pumped as a reflux back to the column under flow control, and to product storage under level control.

The two product methanol tanks (T-4002 A/B) are operated on alternate fill and empty mode.

All control points are set and trended in the Terminal control system.


Air Main: Minor:

Potential:

There are no main emissions to air The process is normally operated with no minor emissions. Although not anticipated during normal operation, if required pressure control on the Methanol Reflux drum can be provided by cold venting to the LP flare stack. The storage tanks are nitrogen blanketed with relief vent to atmosphere. There may be some fugitive hydrocarbon emissions during normal operation. Emergency situations may require depressurisation of the plant using the HIP and LP Flares.

Water There are no direct emissions to surface waters / ground waters from this process unit operation. Still bottoms (i.e. Produced Water) is treated in the Produced Water Treatment System. Operational and maintenance drainage from process areas is collected via a dedicated closed drain collection network and routed to the Closed Drains Drum (D-8201) for either off-site disposal or recovery to process (Refer to Sections E.2 and F. 1.2 of the IPPC Application Form for further information on the Produced Water Treatment system and the Closed Drains system).

Waste The Aqueous Filter and Export Filter cartridges will be periodically replaced and transported off-site for treatment/disposal. Acid washing of the reboiler will remove scale which will be transported off-site for treatment/disposal. Methanol still valve trays and reboiler tubes will require intermittent replacement and will be treated/disposed off-site. Refer to Tables H. 1 (i) and H. 1 (ii) of the IPPC Application Form for details on the waste quantities generated.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

FROM SLUGCATCHER D-l 002

Filter F-l 001

Spent Filter Cartridge ’ WASTE

INLET SEPARATOR D-l 003

COLD SEPARATOR CLOSED DRAlNS A4

D-2007 DRUM D-8201

0 Still Bottoms1 Produced Water

TERMIP FACILT

ATMOSPHERE

Flash Gas LP FUEL GAS SYSTEM ’ (PFD No.6)

:

D ,F&ed/Bpttoms Excha’hger ’

/j&%2?%- ;,“~~“,CEED$VATER

I

I Reboiler Acid Wash

7’ WASTE

HEATING MEDIUM

Coalescer D-4003 Still C-4001

Reboiler B-4001

f

J+ Corrosion/

OFF-SHORE Scale Inhibitor

3 Addition FACILTII

Product - Export Filters f- Storage Tanks

F4002A/B T-4002 A/B

Spent Filter Cartridges

r WASTE

0 PFD No.5 - Methanol Recovery, Regeneration & Chemical lniection

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

This section includes process descriptions and simplified process flow diagrams (PFDs) (where appropriate) for the main utilities at the Terminal. For ease of reference, in the process descriptions, the main equipment is numbered in accordance with the Overall Plot Plan included as Attachment D. 1,

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

D.5.1 Fuel Gas System

Purpose Natural gas that is used as a fuel in the Terminal is referred to as fuel gas. High Pressure (HP) fuel gas is used as a fuel in the sales gas compressor turbines. Low Pressure (LP) fuel gas is used as a fuel in the power generators, as an alternative fuel (to condensate) in the heating medium fired heater, and also provides back-up for the nitrogen flare purge.

Process Description HP fuel gas is sourced from the sales gas supply. A secondary supply is available from the Inlet Gas (after mercury removal) during plant start-up. The gas is pre-heated in the electric Fuel Gas Pre-Heater (E-8403 A/B) and pressure is then let-down to the HP system operating pressure (25-35 barg) as it enters the HP Fuel Gas Knockout (KO) Drum (D-8402) which removes any residual liquids from the gas stream. The gas stream then passes through the electric HP Fuel Gas Heater (E-8402) which provides 20°C superheat before passing to the sales gas compressor turbines.

Some LP fuel gas is sourced from the condensate recovery system (i.e. flash gas) with the balance of the LP fuel gas requirements sourced from the sales gas supply.

Flash gas from the condensate recovery system is compressed to delivery pressure in the LP Gas Compressor (K-3OOlAB) before passing through the LP Gas Compressor KO Drum (D-3003 A/B) which removes any residual liquids from the gas stream. This gas stream combined with the sales gas feed stream are let-down to the operating pressure of the LP fuel gas system as they enter the LP Fuel Gas KO Drum (D-8401) which removes any residual liquids. The LP Fuel Gas Heater (E-8401) then provides 20°C superheat to the LP fuel gas for distribution.


Process Control Both the LP and HP systems are controlled by fuel gas demand. Sales gas is electrically pre-heated to approximately 50°C by the electric Fuel Gas Pre- Heater and then let-down to a pressure of 25 to 35 barg, prior to feeding the HP and LP fuel gas systems. The HP Fuel Gas Heater heats the gas stream to 43.8OC (normal) prior to use in the sales gas compressor turbines.

Gas sourced for the LP System is let-down to the LP fuel gas system operating pressure of 5 barg as it enters the LP Fuel Gas KO Drum. The LP Fuel Gas Heater provides 20°C superheat to the gas before distribution.


For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24


Air Main: Minor:

Potential:

There are no main emissions to air The process is normally operated with no minor emissions. Maintenance activities may require depressurisation of the plant using the Maintenance Flare (used on a limited infrequent basis). Although not anticipated during normal operation, if required pressure control on the LP Fuel Gas KO drum can be provided by cold venting to the LP flare stack. There may be some fugitive hydrocarbon emissions during normal operation. Emergency situations may require depressurisation of the plant using the HP and LP Flares.

Water There are no direct emissions to surface waters / ground waters from this unit operation. Operational and maintenance drainage from process areas is collected via a dedicated closed drain collection network and routed to the Closed Drains Drum (D-8201) for either off-site disposal or recovery to process (Refer to Section E.2 of the IPPC Application Form for further information on the Closed Drains system).

Waste There is no waste generated from this system other than from normal maintenance activities.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

INLET GAS SALES GAS

1 E-8403 A/B 1

HP Fuel Gas Heater E-8402

I GAS

TURBINES

CONDENSATE RECOVERY & STABILISATION (PFD No.4)

Flash Gas

v

LP Gas Compressor K-3001 A/B

b

v LP Fuel Gas

KO Drum D-8401

v LP Fuel Gas

Heater E-8401

I

CONDENSATE STABILISATION (PFD No.4)

FLARE PURGE POWER (BACK-UP) GENERATORS

HEATING MEDIUM HEATER

PFD No.6 - Fuel Gas System

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

.’

;

1.. j,.

: .

: , . : j. . ‘ .A

._..’ :’ %3 l

l

D.5.2 Heating Medium System

Purpose A 40 %wt Tri-Ethylene-Glycol (TEG)/Water mixture is used as a heating medium to provide heating to various Terminal process operations. The use of 40 %wt TEG avoids potential freezing at minimum ambient temperatures and elevates the boiling point of the mixture to safe operating levels.

Process Description The Heating Medium System uses a 40 %wt Tri-Ethylene-Glycol (TEG)/Water mixture with make-up, storage and dedicated drainage facilities provided for system maintenance.

The Heating Medium Storage Tank (T-5001) provides first fill of the system, supplies intermittent make-up to the surge drum, and provides storage of the total inventory of the circuit during shutdown. The Heating Medium Transfer Pump is used to transfer the heating medium to the Surge Drum (D-5001). The surge drum is sized to contain the volume expansion of the total inventory of heating medium that occurs between ambient and normal operating temperatures.

The Heating Medium Circulation Pumps (P-5002 A/B) take suction f?om the surge drum and discharge to the Heating Medium Fired Heater (H-5001) which heats the heating medium fluid. The fired heater has a rating / duty of 4.98 MW (maximum net rated thermal input of 6.25 MW) and is normally fuelled with hydrocarbon condensate with LP fuel gas provided as a back-up fuel. The Heater will incorporate a low NO, burner. The heated heating medium fluid is then distributed to the process users (Inlet Heater, Cold Condensate Heater, Methanol Reboiler and Dump Cooler). The heating medium fluid then returns to the surge drum completing the closed circuit.

The Heating Medium Dump Cooler (E-5001) imposes a duty of 30% of the fired heater duty, and is used during start-up and low flow operation to provide the fired heater with a minimum flow path.

All heating medium header pipework can be drained to the Heating Medium Closed Drains Drum (D-8202), fi-om where it can be pumped to the heating medium storage tank.


Process Control TEG make-up concentration in the storage tank is controlled by dilution of tankered TEG with process water.

Flow throu& the fired heater is flow controlled according to demand with minimum flow through the Dump Cooler.

.‘.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

The heating medium exit temperature from the fired heater is controlled at 170 “C by the furnace burner management system.

Each of the heating medium end users has local temperature and flow control to deliver the necessary duty.



Air Main:

Minor:

Potential:

Combustion by-products from the Heating Medium Fired Heater are discharged via Emission Point A2-3. The process is normally operated with no minor emissions. If required nitrogen can be vented from the Heating Medium Surge Drum to the LP flare stack. The storage tanks are fixed roof with vent to atmosphere. There may be some fugitive hydrocarbon emissions during normal operation. Emergency situations may require depressurisation of the plant using the HP and LP Flares.

Water There are no direct emissions to surface waters / ground waters from this unit operation. Operational and maintenance drainage from the heating medium system is collected via a dedicated closed drain collection network and routed to the Heating Medium Closed Drains Drum (D-8202) for recovery to the storage tank (Refer to Section E.2 of the IPPC Application Form for further information on the Closed Drains system).

Waste The contaminated n-i-ethylene glycol inventory will require replacement and at intervals and will be transported off-site for treatment/disposal. Refer to Tables H. l(i) and H. l(ii) of the IPPC Application Form for details on the waste quantities generated.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

CLOSED DRAINS DRUM D-8202

I TEG MAKE-UP

MAKE-UP WATER

CONDENSATE STORAGE TANKS

i---

ATMOSPHERE EMISSION POINT

A2-3

+ Surge Drum

D-5001 Heater H-5001

PROCESS USERS l Inlet Heater l Methanol Reboiler l Condensate Heater l Dump Cooler

PFD No.7 - Heating Medium Svstem

Combustion By-Products

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

D.5.3 Utility Gases

Purpose Utility gases (instrument air, plant air, nitrogen) are generated on site for utility supply and use as a blanketing gas (nitrogen). Nitrogen is used in the blanketing / purging of process vessels and pipework for safety purposes. The use of nitrogen ensures an inert atmosphere (absence of oxygen) and prevents the occurrence of potentially flammable / explosive atmospheres. The use of nitrogen also minimises hydrocarbon emissions.

Instrument Air The Instrument Air Package (N-8501) supplies clean, dry, compressed air at 10 barg to the Instrument Air Receiver (D-8501). The package comprises 3 x 50% capacity compressors, a wet air receiver and air drier/filter, and provides 1050 Nm3/hr of air. The instrument air leaves the instrument air receiver through instrument air filters for distribution to users via a dedicated header.

Plant Air The plant air is supplied from the instrument air system. The plant air is pressure controlled to 6.5 barg, prior to distribution to users. Normally there are no plant air users. In the event that the plant air consumption draws down the instrument air pressure to 8 barg, a further compressor starts. If the pressure falls below 6 barg, the plant air and nitrogen system isolation valves are closed to avoid further depletion of the instrument air system pressure.

Nitrogen System Nitrogen is generated by the Nitrogen Generation Package (N8601AE9 which consist of 2 x 100% membrane air separation units, and the generated nitrogen is stored in the Nitrogen Receiver (D-8601) at 6-8 barg, prior to distribution to users via a dedicated header. The package is capable of providing 250 Nm3/hr nitrogen to the downstream Nitrogen Receiver, and is fed with compressed air from the instrument air system. A bottled back-up, consisting of two Nitrogen Bottle Racks (N-8602A/B) and a manifold (N-8603) is provided in case of loss of the nitrogen generation.

Process Control All utility gas package systems are locally controlled with feedback and monitoring via the Terminal control system.


Air Main: Minor: Potential:

The process is normally operated with no emissions to air There are normally no minor emissions to air. There may be some fugitive hydrocarbon emissions during normal operation.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

Water There are no direct emissions to surface waters / ground waters from these packages.

Waste Silica gel in the air drier and the membranes from the Nitrogen generation units will be periodically replaced and transported off-site for treatment/disposal. Refer to Tables H. l(i) and H. 1 (ii) of the IPPC Application Form for details on the waste quantities generated.

;. :’ ! a ‘, 1 .‘., .::

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

D.5.4 Potable and Service Water Systems

Purpose The local authority water supply will be used for firewater makeup and will undergo treatment at the Terminal prior to use as a supply of potable and service water.

Process Description It is estimated that the Terminal will require ca. 18 m3/day of water Tom the local authority supply during operation. The local authority supply originates from the potable water treatment facilities at Carrowmore Lake (Barnatra).

The incoming water supply (raw water) is pumped, on level control, through the Raw Water Filters (F-8901 A/B) for particulate removal. Water is disinfected with a Chlorination Package (N-8902) to prevent algae growth in the holding tank and then passes to the Potable Water Tank (T-8901) which is sized for 7 days storage. Firewater make-up is taken off upstream of the Chlorination Package.

The potable water pumps (P-8901 A/B) transfer water from the Potable Water Tank to the W Sterilisation Package (N-8901), where the water is irradiated with ultra-violet light. This sterilises the water to ensure that it is suitable for personnel consumption and safety showers.

Service water is taken from the discharge of the potable water pumps, and transferred to the Service Water Break Tank (T-8902) through a float valve to maintain the level. The service water is used for make-up to the heating medium and chemical systems (e.g. regenerants in water treatment). All water for hosing is taken from the firewater system. The use of the break tank avoids the possibility of back-contamination of the potable water supply. The Service Water Distribution Pumps (P-8902 A/B) supply up to 7.9 m3/hr for distribution to users.


Process Control The potable water tank provides 7 days storage to satisfy the domestic and potable water demand. Chlorination is controlled by continually measuring chlorine residual. The W lamp intensity is continuously monitored and feedback triggers cleaning and replacement.

All potable water systems are locally controlled with feedback and monitoring via the Terminal control system.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24


Air Main: Minor: Potential:

There are no main emissions to air There are no minor emissions to air There are no potential emissions to air

Water There are no direct emissions to surface waters / ground waters from this system.

Waste The inlet filters will generate waste for disposal. The potable water tanks will be cleaned as required and some sludge material may be generated for disposal. Waste streams will be transported off-site for treatment/disposal. Refer to Tables H. 1 (i) and H. 1 (ii) of the IPPC Application Form for details on the waste quantities generated.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

LOCAL AUTHORITY WATER SUPPLY

+ WASTE ( Pa*icu’ates

+

FIREWATER POND T-8701

I

Potable Water Tank T-8901

Potable Water Pumps

P-8901 A/B

c Service Water

Break Tank T-8902

I I 1 UV Sterilisation Distribution

Package Pumps N-8901 P-8902 A/B

, I

DOMESTIC USE AND HEATING MEDIUM SAFETY SHOWERS AND CHEMICAL

SYSTEMS

PFD No.8 - Potable & Service Water System

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

D.5.5 Power Generation

Purpose The power requirements of the Terminal are provided by on-site generator sets fired on natural gas.

Process Description The plant will be self-sufficient in power generation, with 3 x 50% Power Generators (G-8801 A/B/C) each with a rating / duty of 1.32 MW (maximum net rated thermal input of 3.22 MW). The Power Generators will be LP fuel gas fired compression engines incorporating low NO, burners. Each generator set will be capable of supplying half the maximum power demand of the Terminal. During normal operating conditions the power requirement of the Terminal will be supplied by two of the generators running at equal load, with the third unit on standby.

An Emergency Generator (G-8802), with a rating / duty of 0.65 MW (maximum net rated thermal input of 1.9 MW) will provide emergency power to critical users on loss of the normal power supply, or to meet black-start demands. The Emergency Generator will be a diesel fired compression ignition engine. Diesel is stored in a main Diesel Storage Tank (T-8803), and is pumped to the local day tanks for each user through a distribution header by the Diesel Distribution Pump (P-8801). The emergency generator will be provided with its own diesel storage day tank to ensure security of supply.

In the event that the emergency generator were also to fail, then a battery back-up system, known as the uninterruptable power supply (UPS), will take over to allow safe shutdown of all plant systems and to provide minimum power for essential control functions.

Process Control The package control systems include automatic and manual start mode, load sharing and load management. Each unit will include automatic control of output voltage control and frequency. Signal interfaces are provided to the Terminal control system allowing all status and operating data to be displayed in the control room.


Air Main:

Minor:

Potential:

Combustion by-products from the three Power Generators are discharged via Emission Points A2-4, A2-5 and A2-6. Combustion by-products from the emergency power generator are discharged via Emission Point A3-2. There are no potential emissions.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

Water There are no direct emissions to surface waters / ground waters Corn this system.

Waste There is no waste generated fi-om this system other than from normal maintenance activities.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

D.6 Safety Systems This section includes descriptions of the safety systems at the Terminal. For ease of reference, the main equipment is numbered in accordance with the Overall Plot Plan included as Attachment D. 1.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:24

\ j . . . ., ,:’ jj ,( .:,:: .,,.‘J;

@’ D.6.1 Flaring

Purpose Flare systems will be provided at the Terminal for depressurisation of the plant for maintenance purposes (Maintenance Flare) and during emergency situations (HP and LP Flare).

Process Description

Maintenance Flare System The Maintenance Flare System will be used to safely depressurise sections of the Terminal’s gas systems for maintenance during planned shutdowns. Gas filled equipment is manually depressurised into the Maintenance Flare Header, which feeds into the Maintenance Flare Knock Out (KO) Drum (D-8 111) which removes any liquids from the gas stream. The Knock Out Drum is connected to the Maintenance Flare Package (N-81 1 l), with excess gas being routed to the LP flare under pressure control. The Maintenance Flare Package is a ground flare sized for 10 MMSCFD (million standard cubic feet per day) of gas. Ignition of the flare is by a pilot which burns fuel gas, with propane from cylinders being available as back up. The pilot is only ignited during flare use. The flare header is normally purged by nitrogen to ensure that a flammable atmosphere (passing valves) never occurs in the header system.

HP and LP Flare System The plant has two discrete flare systems from High Pressure (HP) and Low Pressure (LP) sources. The emergency flare systems have separate collection headers, knockout drums, stacks and flare tips, but the stacks utilise a common support structure. The HP flare system is sized for a flow of 350 MMSCFD providing full flow relief of the gas export system. The flare header collects all HP relief lines and blowdown lines from the process and passes them to the HP Flare KO Drum (D-8101) for liquids removal. The LP flare system is sized for a flow of approximately of 23.6 MMSCFD. The flare header collects all LP sources ii-om the process and passes them to the LP Flare IS0 Drum (D-8102) for liquids removal. During normal operation, when there is no demand for flaring, the pilots are not ignited. However, when a significant flow of gas is detected to either the HP or LP Flare stacks, pilots on both stacks are automatically ignited by the common Ignition Control System. Propane stored in cylinders is provided as back-up to fuel gas ignition. The flare header is normally purged by nitrogen to ensure that a flammable atmosphere (passing valves) never occurs in the header system.

Process Control The flare system collect all vents fi-om relief valves and route them directly to the appropriate flaring system. All flares have automatic ignition systems. Flare system status is displayed and trended on the Terminal control system.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

Environniental Emissions

Air Main: Minor:

Potential:

There are no main emissions associated with flaring. Combustion by-products fi-om the maintenance flare are discharged via Emission Point A3- 1. Combustion by-products from the HP and LP flares are discharged via Emissions Points A4-1 and A4-2 respectively.

Water There are no direct emissions to surface waters / ground waters from these systems. Operational and maintenance drainage from the process areas is collected via a dedicated closed drain collection network and routed to the Closed Drains Drum (D- 8201) for either off-site disposal or recovery to process (Refer to Section E.2 of the IPPC Application Form for fixther information on the Closed Drains system).


: . . . . i

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

Purpose The firewater system provides water for fire-fighting purposes and delivers water to hydrants, monitors, automatic deluge systems, foam systems and hose reels at the Terminal.

l

Process Description Water for fu-e-fighting purposes (i.e. firewater) will be stored in the Firewater Pond (T-8701). The design capacity (peak demand) of the firewater system is 1200 m3/hr which is based on the worst case fire scenario of a condensate tank fire with simultaneous deluge of the affected tank and adjacent tanks, the latter requirement to prevent escalation. The firewater supply will be provided by 4 No. 50% Firewater pumps (P-87OlAilYUD) fired on diesel. Two electrically driven Jockey Pumps (P- 8702A/B) are provided sized at 5% of fire pump capacity and sufficient for one hydrant. Due to the remote location of the Terminal from the nearest emergency services, a total of 6 hours storage (7200 m3) of firewater will be provided in the Firewater Pond. Makeup water to the pond will be provided by local freshwater supplies.

The fire mains (ringmain) is a 16 inch (diameter) grid system designed to provide a minimum discharge pressure of 7.0 barg at the furthest monitor or hydrant and the pressure range requirements for the worst case use of nozzles for the deluge/foam systems. The ringmain contains sectionalising valves capable of isolating various sections of the fire main for maintenance purposes.

Hydrants provide a source of firewater for the fire hose, portable monitors, mobile foam units, mobile foam trailers and fire fighting vehicles. Water monitors provide a source of firewater for extinguishing and cooling vulnerable parts of equipment, storage tanks and structure throughout the Terminal. The monitors are operated at a location remote from the monitor location. Fixed firewater deluge systems are provided for the protection of hydrocarbon tanks, pumps, compressors, vessels and tanker loading areas. Fixed roof tanks, with or without internal floating roof, containing condensate or methanol, have fixed foam chambers designed to pour foam solution onto the liquid surface.

Process Control A fire detection system will initiate alarms in the control room from where the firewater system will be initiated. The tire-main contains sectionalising valves capable of isolating various sections of the fire-main for maintenance purposes. Each deluge system is capable of local manual operation at the skid and remote operation from the control room.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25


Air: Main: Minor:

There are no main emissions from the firewater system. Combustion by-products from the firewater pump engines are discharged via Emission Points A3-3, A3-4, A3-5 and A3-6.

Potential: There are no potential emissions from the firewater system.

Water: Used or contaminated firewater is collected in the Open Drains System and routed to the Used Firewater Pond (T-8306) prior to appropriate treatment / disposal. Refer to Section J of the IPPC Application Form for further information.


For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

D.6.3 Nitrogen Blanketing

Purpose Nitrogen will be used for blanketing / purging of process vessels and pipework. The use of nitrogen ensures an inert atmosphere (absence of oxygen) and prevents the occurrence of potentially flammable / explosive atmospheres. Nitrogen will be provided to tanks, flare headers and also for compressor gas seals.

Refer to Section D.5.3 on Utility Gases for further information on nitrogen generation and use at the Terminal.

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

Contents

0 Attachment E.l.A.1 Drawing Showing Location of Emission Points to Atmosphere (Drg No. 010159-22-DR-0004)

. ;i. ‘)

: ZY

. . .

< ,’ i

;~. r , I , ”

. ,

‘. \ If:

,I.%

I:..

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25


has been extracted fkom this location in the document and has been stored in a separate file.

(This is due to file size issues.)



Licence: PO73 8-O 1

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

NO ATTACHMENTS

.:

I .#:<, : : . , I . i, ; : ,> : . ,

I “I;.’ ;.L :._ -?&~,‘:‘.... _ ?

I . .

. : 1

. .

: . : ,’

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

, . . : ‘, .11”

_- , ; , . . . ,’ ”

: , , . . .

Contents

‘.O Attachment E.2.1 Terminal Drainage Plan (Drg No. L3882-030-110-0173)

Attachment E.2.2 Perimeter Drainage Layout-Surface Water (Drg No. CO60)

Attachment E.2.3 Drawing Showing the Tre,ated Water Pipeline Route From the Terminal to the Sea Outfall Location (Drg No. 188 Rev.01)

Attachment E.2.4 Site Plan Showing Location of Emission Point to Surface Waters (Drg No. 010159-22-DR-007 Rev B)

Attachment E.2.5 Rainfall Data for Belmullet Meteorological Station

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25




The extracted content can be found in the followitig electronic pdf file:


Licence: PO73 8-O 1

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25





‘.

Application Form-Drawing- 1 0

Licence: PO73 8-O 1

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25





Application Form-Drawing- 11

Licence: PO738-0 1

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25


has been extracted from this’ location in the document and has been stored in a separate file.




Licence: PO73 8-O 1

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

--. I : -f I: I:

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

Extreme Rainfall Return Periods ocation: Belmullet, Co. Mayo .verage Annual Rainfall: 1108

iaximum rainfall (mm) of indicated duration expected in the indicated return period.

Wation min min min 0 min 5 min 0 min Omin hour hour hour

2 hour 4 hour 8 hour 6 hour

l/2 1 Return Period (years)

2 5 10 20 50 IO 1.7 1.9 2.2 2.8 3. 2.9 3.3 3.9 4.8 5. 5.1 5.9 7.0 8.7 9. 7.4 8.6 10.2 12.8 14.

4.7 5.9 6.6 8.9 10.8 12.9 16.4 1 6.2 7.8 8.7 11.7 14.1 16.8 21 2 a.3 10.1 11.3 15.0 17.9 21 26 3

10.9 13.4 14.7 19.1 23 26 32 3 14.8 17.8 19.4 25 29 33 40 4 17.9 21.4 23 29 34 39 46 z;

22.9 27 30 37 42 48 57 E 28 33 36 45 51 5% 68 7 35 41 44 54 61 69 81 E

otes: Larger margins of error for 1, 2 ,5 and 10 minute values and for 100 year return periods M560: 15 M52d: 51 M560/m52d: 0.29

. : ,.l

. r

. . .’

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

i .

,>

. :

:

-.

% .

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

‘,’ . . , ‘ . , . , . . .

. , . , _ *

, : - : , , * I - - . _

3 . . ; :

-:,,., : _,., . ,, :.

i i *.::, _‘, .:o d’.

_.,a

NO ATTACHMENTS

’ r,.. /. .I ., . . . _’ .

,,. , . j L :. ..‘:

.;

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

0

2.

.’

: :

- ‘..

-_’

. “Tj ‘: , , . ,

, ; . : 8;; . . : , . . :

. : : , , , . A ) , , : , ”

Contents

Attachment E.5.1 Drawing Showing Location of Noise Sources (Drawing No. 010159-22-DR-0005 Rev.C)

‘. 21; ‘.., ..,

.;-

‘.,,_ ~..

d.

; . , , , I

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

Placehdder . This page has been inserted to indicate that content



The extracted content can be found in the following electronic- pdf file:


Licence: PO73 8-O 1

For

insp

ectio

n pur

pose

s only

.

Conse

nt of

copy

right

owne

r req

uired

for a

ny ot

her u

se.

EPA Export 25-07-2013:16:18:25

Documents

Attachment C.l Organisational Chart for Terminal Operation