attachment a.1 non technical summary · operations and maintenance (o&m) contractor, with...

LUMCLOON ENERGY LTD. ATTACHMENT A: NON TECHNICAL SUMMARY

Attachment A.1

Non Technical Summary

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CONTENTS

A NON TECHNICAL SUMMARY...................................................... A-1

A.1 General......................................................................................A-1

A.2 Proposed Site Location................................................................A-2

A.3 Management of the Installation ...................................................A-3

A.4 Infrastructure and Operation.......................................................A-4

A.5 Emissions and Impact on the Environment...................................A-7

A.5.A Atmospheric .......................................................................................A-7

A.5.B Surface Waters ...................................................................................A-8

A.5.C Sewer.................................................................................................A-8

A.5.D Ground...............................................................................................A-8

A.5.E Noise..................................................................................................A-8

A.6 Control and Monitoring ...............................................................A-9

A.7 Resource Use, Materials Handling and Energy Efficiency ...............A-9

A.8 Accident, Prevention and Emergency Response ..........................A-11

A.9 Remediation, Decommissioning, Restoration and Aftercare .........A-13

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A-1

A Non Technical Summary

A.1 General

Lumcloon Energy Ltd. is applying to the Environmental Protection Agency for an Integrated

Pollution, Prevention and Control Licence for the operation of a gas fired power station at

Lumcloon Cloghan, Co. Offaly. The facility is classed under Class 2.1 “the operation of

combustion installations with a rated thermal input equal to or greater than 50MW” of the

First Schedule of the Protection of the Environment Act, 2004.

The proposed plant will have capability of producing up to a maximum of 350MWe. The plant

is described as a flexible mid-merit power plant capable of running in either open cycle or

combined cycle modes. The proposed power block will comprise four small scale (<50MW)

gas turbines, four heat recovery steam generators (HRSGs) and two steam turbine generators

producing 75MW. Diverter dampers will be installed between the gas turbines and the heat

recovery boilers and this will enhance the generating flexibility of the plant, i.e. the plant will

be capable of responsively altering its load profile to respond to system demand determined

by the Transmission System Operator (TSO). The plant will be capable of starting up and

reaching full load in open cycle (188MW) mode in 25 minutes. In combined cycle mode,

typical start-up times are as follows:

• From cold start (i.e. plant shutdown for more than 64 hours), the plant will take

approximately 300 minutes to reach full load

• From warm start (i.e. plant shutdown for less than 64 hours), the plant will take


• From hot start (i.e. plant shutdown for less than 8 hours), the plant will take


Each HRSG will also be fitted with supplementary gas burners thereby producing additional

output. The supplementary firing ramp-up rate is around 3MW per minute; which means that

the load can increase from combined cycle operation to maximum load within 10-minutes.

The power plant is designed and configured to allow for high efficiency base load, while also

providing for peak power capacity through out a wide load range. The design concept with a

total of four gas turbines and two steam turbines allows for operation at a high efficiency and

low emissions values throughout a wide plant power output by the possibility to reduce the

power on the gas turbines one by one.

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A-2

A.2 Proposed Site Location

The Lumcloon Energy Ltd power plant will be located on 11 acres of development lands,

which are under the applicant company’s control. The site is situated in the town land of

Lumcloon, approximately 5km south east of Ferbane, 22km south of Athlone and 20km west

of Tullamore. Maps showing site location, existing site layout and proposed site layout are

attached.

The site itself is a brownfield site and formed part of the former Ferbane peat fired power

station site, which was operated by the ESB and fully decommissioned in 2004. The ESB

subsequently obtained planning permission in 2004 for a 100MW gas fired power plant at the

site, but did not proceed with the proposed development. An IPPC licence (IPC Licence

Registration Number P0695-01) was also obtained but has ceased to have effect and the

activity cannot now commence under this licence in accordance with Section 92(1) of the EPA

Acts, 1992 and 2003.

The development site is approximately 11 acres and located adjacent to the R357. The site is

about 5km south east of Ferbane, 22km south of Athlone and 20km west of Tullamore. The

proposed development lands are brownfield and the site is part of the former ESB owned

peat fired power station site, which was decommissioned in 2004. The site is situated in the

Shannon River basin district and the Silver River is located approximately 50m to the East of

the site and flows north into the Clodiagh, which joins the Brosna River, which in turn flows

into the River Shannon. There is a relatively small wooded area in the north western area of

the site. There are large parcels of cutaway bogland and forestry to the south west and

north-west of the site and industrial railway associated with the former peat power station

run out from the former peat power station to the surrounding boglands. The surrounding

topography is generally flat with nearby once-off rural housing primarily located south west of

the site along a local road, which borders the site to the west and runs in a south western

direction from the R357 to the R437.

An Bord Pleanála granted planning permission with conditions for the proposed Lumcloon

Energy Ltd. power station development in March 2010. The plant will have capability of

producing up to a maximum of 350MW of power. The power generation plant will be capable

of running in either open cycle or combined cycle modes. The power block will comprise four

small scale (<50MW) gas turbines, four heat recovery steam generators (HRSGs) and two

steam turbine generators producing a further 75MW. Diverter dampers will be installed

between the gas turbines and the heat recovery boilers and this will enhanced the generating

flexibility of the plant. For example, the four gas turbines in open cycle mode will be capable

of producing electricity in the range of 47MW to 188MW. In the event of shutdown of one of

the steam turbines, the plant would still be capable of producing approximately 224MW of

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A-3

power (i.e. operation of two gas turbines in open cycle mode and two gas turbines in

combined cycle). The plant will be capable of starting up and reaching full load in open cycle

(188MW) mode in 25 minutes.

The power plant will be designed and configured to allow for high efficiency base load, while

also providing for peak power capacity throughout a wide load range. The design concept

with a total of four gas turbines and two steam turbines allows for operation at a high

efficiency and low emissions values throughout a wide plant power output by the possibility

to reduce the power on the GTs one by one.

Natural gas, supplied from the Bord Gáis Network (BGN) grid, will be the primary fuel source

for the facility. To comply with Commission for Energy Regulation (CER) regulations, diesel

will be used as a backup fuel in the event of interruption to the natural gas supply. Five days

running capacity of diesel will be stored on site, (approximately 5,200m3).

The proposed facility will operate as a mid merit plant and the proposed hours of operation

will be determined by the Transmission System Operator (TSO), Eirgrid, based on the load

demand of the electricity grid.

This Non -Technical Summary (NTS) is submitted as part of the supporting documentation for

the IPPC Licence application. This section of the NTS provides a brief overview of the

application only. It is recommended that the entire document is reviewed in order to obtain

detailed information relating to the application.

A.3 Management of the Installation

Lumcloon Energy will have the ultimate responsibility for health, safety and environmental

issues relating to the operation of the facility. A suitably qualified and technically competent

Operations and Maintenance (O&M) Contractor, with previous experience operating and

maintaining power plants will be contracted by Lumcloon Energy Limited. The O&M

Contractor will have responsibility for the day to day operation and maintenance of the plant

as well as environmental monitoring and reporting. The contract between the Operator and

the O&M Contractor will specify health and safety and environmental obligations and

responsibilities.

The plant manager will report directly to the director of Lumcloon Energy Ltd. Site specific

management systems and operating procedures will be developed. The systems and

procedures will be continuously reviewed and developed by the operator and O&M contractor

in accordance with the principles of continuous improvement. The Plant Manager will be

directly responsible for the implementation of the Operators Health and Safety; all other site

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A-4

personnel will have varying degrees of responsibility for their implementation. Operations will

be carried out in accordance with legislative requirements and the conditions of the IPPC

Licence and Planning Permission.

All personnel will be technically competent and suitably qualified to undertake their assigned

tasks. Training records will be maintained on site, available for inspection.

Personnel with responsibilities for operations, maintenance, health and safety and the

environment will receive task specific technical training, as required. A training needs

programme and matrix will be developed and updated on a regular basis. The programme

will take account of any incidents, amendments to site licence conditions, changes to

legislation, operations, operating procedures, emergency response and best practice

guidelines.

A site specific EMS will be developed and implemented for the facility in accordance with

ISO14001:2004 in due course. The EMS will provide the framework for environmental

management, ongoing assessment of environmental performance and continual improvement

at the power plant. The implementation of the EMS will include regular cross-functional

management reviews and will be subject to both internal and external audits.

A.4 Infrastructure and Operation

The site is predominantly flat generally ranging in height (between 45m ordnance datum

(OD) and 47m OD Malin Head datum).

Access to the site will be from the R357 through the existing entrance/exit to the site. This

will be used as the main entrance and is located beside the administration building in the

north-west area of the site. A second entrance for emergency use further east along the

R357 towards Lumcloon Bridge will be installed.

A two storey administration building will be constructed which will be 10.6m to roof apex

from ground level. Approximately 30 car parking spaces will be provided for employees and

visitors in this area of the site during the operation of the plant. A 400 m2 warehouse

containing a workshop and stores will be located south of the administration block, adjacent

to the switchyard.

The power generation building comprising gas turbine halls, steam turbine halls and heat

recovery steam generator halls) will be constructed as one structure with different roof

heights determined by the plant components within. The total footprint of the power

generation building will be 6,684m2. Two air cooled condenser (ACC) units, each with nine

fans will be located on the eastern side of the power block. The parapet of both ACC units

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A-5

will be 24.5m above ground level. A description of all plant components is provided in table

1.0. The tallest structures on the site will be the four exhaust stacks from the HRSG units.

Internal roadways will be tarmac paved and the ground around external plant components

such as the AGI, gas receiving, switchyard and the ACCs will be covered with stone chippings

to facilitate natural drainage.

Table A.4.1 Details of the Facility Components

Component

• Gas Turbine Hall (2 no) – open cycle

• Heat Recovery Steam Generator Hall (2 no)

• Steam Turbine Hall (2 no.)

• Air Cooled Condenser (2 no.)

• Ancillary area of power generation building (1 no.) -ctrl room, lab, etc

• Open Cycle Stacks (4 No.)

• Heat Recovery Steam Generators (HRSG) stacks (4 No.)

• Administration Building (1 no.)

• Warehouse/Workshop/Stores (1 no.)

• Switchyard (1 no.)

• Above ground Installation (1 no.)

• Internal Roads and Car parking

• Bund for Diesel Storage (1 no.)

• Diesel Tank (2 no.)

• Fuel Oil supply pumps canopy (1 no.)

• Raw Water Tank (1 no.)

• Water Treatment Plant (1 no.)

• Demineralised Water Tanks (2 no.)

• Process Wastewater Treatment compound (1 no.) - underground

• Storm water Attenuation tank (1 no.) - underground

The structural design of the main buildings will be conventional structural steel supported on

reinforced concrete foundations. Steel columns will be fire protected as necessary to comply

with the building regulations. Floors will be concrete. The administration building and some

of the smaller buildings will be concrete block construction on concrete reinforced concrete

foundations and rendered with nap plaster finish. Profiled metal cladding will be used for

external walls on power generation buildings. The finished colour of the plant structures will

be designed to favour the reduction of potential visual impacts. Non reflective finishes will be

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A-6

used in order to reduce or avoid impacts relating to sunlight reflection or glare. Colours of

buildings will be confirmed with the planning authority prior to construction.

Roofs will be constructed of profiled metal decking on purlins spanning between rafters and

will be flat or shallow pitched. Buildings will be single or two storey with access gantries and

walkways for access to plant and equipment. These will be constructed of stainless /

galvanised steel open grating type flooring supported on steel beams and columns. The

stack will be fabricated from painted insulated carbon steel. External doors and escape doors

will generally comprise of metal flush doors and mild steel frame.

It is envisaged that the facility will operate in excess of 6000 hours per annum and is

designed to operated 365 days per year. The mid merit plant will be capable of responsively

altering its load profile to respond to system demand determined by the Transmission System

Operator (TSO) and therefore running time is a function of demand.

The following describes how power is produced from natural gas at the facility.

Gas Turbine Generator

Air enters the gas turbine where it is compressed, mixed with natural gas and ignited, which

causes it to expand. The pressure created from the expansion spins the turbine blades,

which are attached to a shaft and a generator, creating electricity. In simplistic terms a

generator can be described as a large spinning magnet inside a coil of wire and as the

magnet spins, electricity is created in the wire loops. The hot exhaust gas exits the turbine

and then passes through the Heat Recovery Steam Generator (HRSG).

Heat Recovery Steam Generator (HRSG)

Within a HRSG, there are layers of tall tube bundles, filled with high purity water. The hot

exhaust gas coming from the turbines passes through these tube bundles, which act like a

radiator, boiling the water inside the tubes, and turning that water into steam. The gas then

exits the power plant through exhaust stack(s) at a much cooler temperatures, after having

given up most of its heat to the steam process.

A.4.A.(a) Steam Turbine Generator

The steam generated is sent to the steam turbine. Steam enters the turbine at very high

temperatures and under high pressure. The pressure of the steam is used to spin turbine

blades that are attached to a rotor and a generator, producing additional electricity. After the

steam is spent in the turbine process, the residual steam leaves the turbine at low pressure

and low heat, and passes into a condenser, to be turned back into water. By using a

combined cycle, the plant is capable of producing more electricity. A CCGT generator can

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A-7

reach efficiency levels of up to 58%. The efficiency of the proposed CCGT unit means that

this type of generator emits the lowest levels of greenhouse gases per unit of electricity

generated when compared to any conventional generation type.

Flexible mi-merit plant, such as the one that will be installed at Lumcloon, is capable of

varying the power generation across a wide range of power output and can turn on and off

on a daily basis, which allows this unit to maximize the electricity generating potential from

variable renewable energy sources such as wind.

A.4.A.(b) Air Cooled Condenser

An air-cooled condenser (ACC) is used to condense the steam exhausted by the steam

turbine. This solution provides a completely plume free arrangement. The hot process fluid

to be cooled flows through a tube while the cooling air flows across the outer surface to

remove heat. The cooling air is propelled by fans in either a forced draft or induced draft

configuration. The ACC significantly reduces the demand for water (closed loop) and does

not give rise to a visible water vapour plume.

A.5 Emissions and Impact on the Environment

A.5.A Atmospheric

The current air quality in the area of the proposed development was determined through the

use of baseline monitoring using diffusion tubes and a desk study review of published data

available from the EPA and nearby developments. The baseline air quality assessment

determined that existing baseline levels of PM10, NO2, SO2 and benzene are significantly

below the ambient air quality standards in the region of the proposed development.

Air dispersion modelling was undertaken to assess the likely emissions arising from the

proposed power plant, during its operation. A stack height determination was undertaken for

eight stack emission (A2-1 to A2-8) to ensure that appropriate stack heights were determined

for the relevant combined cycle and open cycle emission points. This measure will ensure

that the impact on local air quality will not be significant. The potential air quality impacts

during the operational phase were assessed, based on a ‘worst-case’ scenario approach by

modelling emissions from the eight stacks at the limits which will be imposed on the

development. The assessments predicted that emissions will result in ambient air quality

concentrations that are within the relevant air quality limit values regardless of firing on

natural gas or distillate in combined or open cycle modes of operation.

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A-8

The power plant will be designed to the highest modern standards and will operate in

accordance with BAT (Large Combustion Plant) techniques to ensure minimum emissions

from the plant. In addition to IPPC licensing requirements, the facility will also be regulated

under the Greenhouse Gas Emissions Permit regimes, ensuring emissions from the facility and

their impact are minimised.

A.5.B Surface Waters

The discharge from the facility will comprise treated process waste water discharge, surface

water run-off discharge and treated foul water discharge. The three emission points (SW1 to

SW3) are discharged into the open drain at the northern boundary of the site which is

culverted at the north east corner of the site where subsequently discharges into the Silver

River.

An assimilative capacity assessment (ACA) was undertaken on the Silver River to provide

precise quantifiable impacts on the receiving water body. This assessment took account of

the proposed foul water discharge, process water discharge and discharges from the proposed

(yet to be constructed) adjoining site to the south and typical discharge concentrations from

similar plants and the proposed plant. The ACA study determined that the proposed discharge

will result in a low quantity of the assimilative capacity of the Silver River being taken up by

proposed discharge.

A.5.C Sewer

There will be no discharges to sewer from the activity.

A.5.D Ground

There will be no discharges to sewer from the activity.

A.5.E Noise

A noise impact assessment was undertaken which considered the existing noise environment,

the predicted noise impact, possible noise mitigation and the residual impact of the proposed

power plant. The closest residential receiver to the power station is approximately 400m

away with two residential receivers located approximately 600m away. The distance of the

proposed power plant from the nearest residential receivers allows for significant noise

attenuation due to distance. When all major noise sources on the proposed site were

modelled, it was found that the noise impact at the three residential receivers is predicted to

be below the EPA noise limits of 55dB LAr,T during daytime (8am to 10pm) and 45 dB LAeq,T

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A-9

during night time (10pm to 8am). As the power station will be operation on a 24 hour basis,

the night time scenario defines the actual noise limit on the power station. It is concluded

that the noise impact due to the power station will not result in an exceedance of the relevant

EPA limit values and the recommended daytime and nighttime noise levels in the World

Health Organisation (WHO) Guidelines for Community Noise.

A.6 Control and Monitoring

The activity will operate in accordance with the 2008 BAT Guidance Note for the Energy

Sector (Large Combustion Plant Sector).

The gas turbines at the facility will use dry low emissions technology. Dry abatement will

eliminate the need for production and storage of large quantities of demineralised water for

emissions control purposes. It will also significantly reduce the quantity of process

wastewater (demineralisation process and wet scrubbing process) produced at the facility

during its operation. Dry abatement reduces emissions without reducing efficiency of the

plant.

The proposed facility was designed to incorporate an air cooled condenser thereby

significantly reducing the potential volumes of water consumption and process waste water

generated from the site. A combination suitable abatement measures and monitoring

(routine and continuous) will ensure that emission to atmosphere from stacks (eight) and to

surface water from storm, foul and process wastewater do not adversely impact on the

receiving environment. Ambient environment monitoring will also be undertaken for noise

and surface water (upstream and downstream of the plant on the Silver River).

A.7 Resource Use, Materials Handling and Energy Efficiency

The primary raw materials which will be used at the site are:

• Natural Gas

• Water

• Distillate (Diesel for use as a back up fuel)

Natural gas will be supplied from Bord Gáis Network’s (BGN) at a minimum guaranteed

pressure of 19 bar gauge (bar(g)) and 15oC. The design maximum pressure of the BGN gas

pipeline is 70 bar(g). The pressure of the gas will be regulated to approximately 35 bar(g) in

the AGI. From this compound, gas will be sent to gas receiving plant for conditioning. The

gas conditioning plant located close to the gas turbine hall. It is estimated, based on

operation 365 days per annum, that the annual gas usage will be 5.8 x 108m3 natural gas.

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A-10

Process water will be sourced from the onsite groundwater abstraction well (served the

former peat fired power station). Raw water will be stored on site in a tank of approximately

3,500m3 capacity. Water will be pumped from the raw water storage tank to the water

demineralisation treatment plant for use in the power generation process. The raw water

storage tank will also serve as a reservoir for fire fighting purposes. An on site water

treatment plant will be required to treat abstracted groundwater for use in the HRSG. Water

will be demineralised to achieve a high purity. The primary reason for process water

treatment is to maintain the integrity and performance of the power plant. Critical plant

applications have water purity or conditioning requirements that must be adhered to for safe,

reliable and efficient power generation. Potable water will be obtained from the Leabeg –

Leamore Group Water Scheme. It is estimated that a maximum of 3.5m3 per day of potable

water will be required for use at the facility, i.e. canteen, washing facilities, etc.

Diesel, to be used as a backup fuel, will be stored in a cylindrical steel tank within a 110%

capacity bund to comply with bunding requirements. Due to the quantity of stored diesel,

estimated an approximately 5,200m3 within two tanks of a combined storage capacity of

6,000m3, the facility is classified as lower tier COMAH in accordance with the requirements of

European Communities (Control of Major Accident Hazards Involving Dangerous Substances)

Regulations 2006 (S.I. No. 74 of 2006). In accordance with legislative requirements, a major

accident hazard (MAH) report was prepared for the proposed development.

Other chemical will be stored and used during the operation of the facility including,

lubricating oils, hydraulic oils, transformer oils, boiler feedwater conditioning chemicals, pH

adjusting chemicals for process wastewater treatment and small quantities chemicals for use

in the on-site test laboratory.

The proposed power plant at Lumcloon compliments that outlined for Mid Merit type plant.

Mid-merit units are modern, efficient power plants that can come on-line quickly in response

to increases in the demand for power. The plant design was selected to ensure that delivery

of an efficient, flexible and responsive plant which will conform to commercial, regulatory,

transmission system requirements and environmental objectives.

Efficiency is dependent on many factors including the plant design, the O&M programme and

the ambient conditions (temperature and barometric pressure).The power plant is designed

and configured to allow for high efficiency base load, while also providing for peak power

capacity through out a wide load range. The plant design includes a total of four gas

turbines, four HRSGs and two steam turbines. This will ensure that the plant can operate at

a high efficiency and produce minimal emission throughout a wide plant power output by the

option of reducing the power on the GTs one by one.

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A-11

By operating the plant in combined cycle (Heat generated by combustion of gas in the gas

turbine will be recovered as steam in the HRSG and the steam is used to drive the steam

turbine), the plant is capable of producing more electricity. A combined cycle gas turbine

(CCGT) generator can reach efficiency levels of up to 58%. The efficiency of the proposed

CCGT unit means that this type of generator emits the lowest levels of greenhouse gases per

unit of electricity generated when compared to any conventional generation type.

Heat generated by combustion of gas in the gas turbine will be recovered as steam in the

HRSG and the steam will drive a steam turbine. Low pressure steam from the steam turbine

will be used in the de-aerator and other plant uses. The gas and steam turbines will be

coupled to a generator for power generation. Supplementary firing using natural gas and

refinery off-gas will increase the energy efficiency.

Energy efficiency and energy optimisation measures will also be considered and implemented

as part of the detailed design and operation of the plant, including those related to building

structures, equipment (pumps, fans, etc) transport on site, employee training and awareness

and housekeeping. The EMS will also include measures for monitoring and reducing energy

usage on site.

A.8 Accident, Prevention and Emergency Response

All employees will receive comprehensive induction training prior to commissioning of the

plant. In addition, site personnel will receive Emergency Response, EMS and general

Environmental Awareness Training, incorporating resource usage, waste minimisation,

energy, water minimisation and noise control techniques. All personnel will be informed of

their responsibilities to report any and all potential and actual non-compliance issues to the

EHS Manager, the EMS auditing programme will facilitate the process. Additional

environmental, health and safety training, including fire fighting and first aid, will be

implemented. The Safety and Emergency response provision at night, weekends and holiday

periods will be the same as during normal working hours.

From the control room, the plant operators will monitor and operate the facility, via the plants

‘Distributed Control System’, viewing graphic representations of all MEC systems on various

screens. The system gives operators both audible and visual signals to keep them informed

of plant conditions at all times and to determine when preventative maintenance is required.

The installation of emergency spill containment facilities will mitigate against any potential

adverse impacts to the receiving surface waters arising from an accidental spillage. All bunds

and chemical containers will comply with the appropriate standards. All bunds will be leak

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A-12

tested prior to commencement of operations. All containers and bunds will be inspected

regularly to ensure they have not become damaged or degraded.

General plant drainage consists of effluents produced by sample drains, equipment drains,

equipment leakage, area wash-downs, etc. This effluent will be collected in a system of floor

drains and sumps and routed to the condensate pit which represents the lowest drainage

point in the plant. From there it is delivered to the process wastewater treatment plant via a

water/oil separator. The process wastewater treatment plant will comprise a below ground

concrete structure containing a number of chambers which will allow agitating, pH and

temperature correction. Continuous monitoring will be undertaken in the final chamber for

dissolved oxygen, pH, conductivity and temperature. Treated process wastewater will then

be discharged to the wastewater collection system to the Silver River via the discharge point

located in the north eastern corner of the site. An onsite laboratory will also be provided to

facilitate monitoring of specific parameters on site.

All appropriate measures will be taken to minimise the risk of accidental spillages or leaks.

The backup supply of diesel will be stored in a cylindrical steel tank within a 110% capacity

bund. The maximum fill level for 2,600m3 is 5.3m. The bund walls will be of reinforced

concrete, 1.6m high. The total volume thus enclosed equates to 110% of the combined tank

capacity. During times when chemicals are handled isolation valves are to be closed. This is

to assure that accidentally spilled chemicals do not enter the storm water drain. The isolation

valves will only be opened again once it has been assured that contamination of the

downstream system can be excluded.

Water collecting in the bund will be pumped to oil/water interceptor prior to being the surface

water attenuation tank. All other surface water runoff from hard standing areas and roofs will

be directed through a hydrocarbon interceptor and silt trap prior to discharge to the

attenuation tank. Small areas that have the potential for causing oil contamination of surface

drain water will be separated from the overall surface water drainage. This comparably low

volume of surface water with potential for oil contamination will be collected separately and

routed through a water/oil separator and delivered to the plants effluent sump.

In case of fire, the applied fire fighting water will be drained into a system of floor drains and

sumps and routed to the condensate pit which represents the lowest drainage point in the

plant. From there it is delivered to the process wastewater treatment plant via a water/oil

separator and the resulting streams will finally be delivered to the plants storm water drain or

effluent drain. A Fire Emergency Response Management plan will be drawn up in consultation

with the local fire brigade and Offaly County Council.

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A-13

Collected surface water will be delivered to the clients storm water drain. In order to assure

that uncontaminated surface drains are not mixing with possibly oil contaminated surface

drains such ‘oil risk areas’ drain into a separate sewer. Such surface water will be treated as

effluent, routed via an oil separator and finally delivered to the client’s effluent drain.

In accordance with the requirements of the 2008 BAT Guidance Note for the Energy Sector

(Large Combustion Plant Sector), the gas turbines will use dry low emissions technology. Dry

abatement will eliminate the need for production and storage of large quantities of

demineralised water for emissions control purposes. It will also significantly reduce the

quantity of process wastewater (demineralisation process and wet scrubbing process)

produced at the facility during its operation. Dry abatement reduces emissions without

reducing efficiency of the plant. Particulate and sulphur dioxide emissions from gas-fired

plant are very low and control measures are generally not required.

The proposed implementation of an Environmental Management System (EMS) at the facility

will address emergency response procedures governing spillages, fire, flooding and malicious

damage.

A.9 Remediation, Decommissioning, Restoration and Aftercare

Subject to the granting of an IPPC licence it is anticipated that operations at the facility will

commence in the first quarter of 2014, the plant is expected to be operational for 30 years.

A detailed Residuals Management Plan will be developed and submitted to the EPA within six

months of commencement of operations, or as otherwise agreed with the EPA, in accordance

with Guidance on Environmental Liability, Risk Assessment, Residuals Management Plans and

Financial Provision, EPA (2006). The plan will be reviewed annually as part of the Annual

Environmental Report (AER) and will take into account forward financial planning for the

process.

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Site Location

0 1,000 2,000 3,000 4,000500

Meters

Note: Geological Data Copyright Geological Survey of Ireland andGovernment of Ireland Reproduced under Licence

Note: Base Map Copyright Ordnance Survey Ireland and Government of Ireland Reproduced under licence, number EN 0004909

© WYG

Drawn By: Igor Wodyk - ArcMap 9.3 WYG IrelandAttachment B.2.A

Job Number:CE07335

Finalised by: GB

Date: June 2009

Office: 1404

Client: Lumcloon Energy Ltd.Site Location Map

1:50,000

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WYG

NOTE: Drawing is for diagrammatic purposes only. No measurements to be taken.

©

Lumcloon Energy Ltd

WYG Ireland

Existing Site Layout

Job No. CE0 7335Figure No.1.2 Finalised By - CS

Date. Aug 2009

Office - 1404

Drawn By: Igor Wodyk - CS2,Illustrator

N

Site BoundaryRoadRiver/ Water CourseBuilding/StructureMonitoring Borehole LocationTrial Pit LocationSurface Water Sampling PointAir Monitoring LocationNoise Monitoring LocationDust Monitoring LocationSlope/GradientWater Table (m.OD)Groundwater Contour (m.OD)Groundwater Flow DirectionCross Section A-A’

LEGEND

BHTP

SWAND

10

A A’

0

METRES

25 50 75

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attachment a.1 non technical summary · operations and maintenance (o&m) contractor, with...

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