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Appendices
Appendix A
Section B.10 Seveso Regulations
Attachment B.10 Maximum Likely Quantities On-Site & COMAH Thresholds.
Appendix B
Total Suspended Solids at SP1 - October 2013 to March 2014 including and without rainfall
Appendix C
Section I.2.2 - Discharge of uncontaminated surface water runoff to drainage ditch (SW2).
Appendix D
Assessment of the impact of sediments in the discharge on the shallow Carrowmore Lake.
Appendix E
Bellanaboy Bridge Gas Terminal – Updated Operational Noise Emissions Models
Appendix F
Section E.2.2. Table E.6 - Summary of Proposed Discharge to Surface Waters - for points SW1 and SW3
Annex 1: Table/ Attachment Table E.2 (i) - Emissions to Surface Water for points SW1 and SW3
Table I.2 (i) – Surface Water Quality
Drawing E.2.1 Corrib Bellanaboy Bridge Gas Terminal Treated Water Discharge Locations.
Appendix G
Non-Technical Summary
Appendix H
Table E.1 (ii) Main Emissions to Atmosphere
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Appendix A
Section B.10 Seveso Regulations
Attachment B.10 Maximum
Likely Quantities On-Site &
COMAH Thresholds
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B.10 Seveso II Regulations
State whether the activity is an establishment to which the EC (Control of Major
Accident Hazards involving Dangerous Substances) Regulations (S.I. No. 74 of 2006)
apply.
If yes, outline how the process comes under these regulations.
Supporting information should be included in Attachment No B.10.
Answer:
The Terminal constitutes an establishment to which the European Communities
(Control of major Accident Hazards Involving Dangerous Substances) Regulations
2006 (S.I. No. 74 of 2006) applies.
The unstabilised condensate, product and raw methanol inventories exceed the
Lower Tier threshold requirements for Articles 6 & 7 of the Seveso II Directive,
requiring notification and preparation of a Major Accident Prevention Policy as
transposed into Irish law by Regulations 10 & 11 of S.I. no. 74 2006 [Ref 2]. No
single inventory on site reaches the requirements of Regulation 12 of S.I. no. 74
2006 (i.e. upper tier threshold, see Attachment B.10). Therefore, based on single
inventory thresholds, the site qualifies as a lower tier site.
Where an establishment has single inventory levels lower than the qualifying
thresholds identified under Schedule 1 (Part 1 and Part 2), then the addition rule
approach is applied to determine if ‘total’ categorised quantities are above or equal
to the qualifying quantity i.e. “1”. From their risk phrases as detailed in safety data
sheets, the materials are divided into ‘toxic’, ‘flammable’, and ‘eco-toxic’ categories
so that their aggregated inventories can be assessed against the requirements of
Schedule 1, Part 2, Note 4 [Ref 2] i.e.
If the sum q1/QU1 + q2/QU2 + … ≥ 1, where qx = the quantity of dangerous
substance x (or category of dangerous substances) falling within Parts 1 or 2 of
Annex 1 and QUX = the relevant qualifying quantity for substance or category x
from Parts 1 and 2, then the relevant provisions apply.
The summation is applied separately to overall hazards associated with toxicity,
flammability and eco-toxicity.
From the calculations involving the aggregated inventories (see Attachment B.10),
the summations are above 1.0 with respect to the upper tier assessment on a
flammability basis, and therefore the site qualifies as an upper tier site.
Ref 1. Seveso II Directive 96/82/EC as amended by Council Directive 2003/105/EC. Ref 2. S.I. No. 74 of 2006 European Communities (Control of Major Accident Hazards Involving Dangerous Substances) Regulations 2006 and associated HSA Guidance notes
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ATTACHMENT B.10 MAXIMUM LIKELY QUANTITIES ON-SITE & COMAH THRESHOLDS Normal Gas and Liquid Level in process vessels (including slugcatcher) as well as High High level in the storage tanks i.e. methanol tanks (product and raw) and condensate tanks
Aggregation quotient
Flammability Toxicity Ecotoxicity
Description Quantity stored (tonne)
Named Lower Upper Lower Upper Lower Upper
Acetylene 0.39 Yes 0.078 0.0078
Aeroshell Fluid 1,41 0.03 No
0.00015 0.00006
Shell Omala 100,150,220 - Lubricant
0.09 No
0.00045 0.00018
Condensate stabilised (Petroleum products)
711 Yes 0.2844 0.02844
0.284 0.0284
Corroless, Cortron CK352, KI 302C (Corrosion Inhibitor)
4 No
0.08 0.02 0.04 0.02
Demulsifier 0.05 No 0.00001 0.000001
Diesel 76.8 Yes
0.031 0.0031
MB-554 Diesel Biocide 0.05 No 0.00001 0.000001
0.0005 0.00025
Hydrocarbon gas (natural gas) 48 Yes 0.97 0.242
Unstabilised Condensate 48 No 4.76 0.95
0.238 0.095
Hydrogen 0.005 Yes 0.001 0.0001
Methanol (Product) 787 Yes 1.574 0.1574 1.574 0.1574
Methanol (Raw - 40% methanol 60% water)
2563 Yes 5.13 0.51 5.13 0.51
Nitric acid 0.05 No 0.001 0.00025
Nynas Nytro Lyra X - Transformer lubricant
4 No
0.07 0.02
80%Tert butyl mercaptan, TBM, 20% Dimethyl sulphide, DMS (Odorant)
9 No 0.0018 0.00018 0.18 0.045
Diethyl-hydroxylamine (DEHA) (Oxygen Scavenger)
2 No 0.0004 0.00004
Propane 0.47 Yes 0.0094 0.00235
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Puraspec 5158 15 No
0.15 0.08
Sodium Hypochlorite Solution 0.5 No
0.005 0.0025
Tectyl 502C 0.02 No 0.000004 4E-07
TOTAL
12.8 1.9 7.03 0.753 0.75 0.225
Notes:
-The above inventories are quoted to normal level for the process vessels and HH levels for storage tanks. -With respect to the defined HH levels for the Product, Raw Methanol & Condensate storage tanks, this equates to all storage tanks full to the LAHH. However, e.g. the typical/normal expected inventory for the Raw Methanol Storage tanks will be 2 out of 3 tanks full to the LAH. -The above is presented as the maximum likely inventory on site. This is a conservative scenario given typical operating levels in the tanks will be below the values quoted.
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Appendix B
Total Suspended Solids at SP1 -
October 2013 to March 2014
including and without rainfall.
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Page 1
0.0
0.5
1.0
1.5
2.0
2.5
3.0
0
5
10
15
20
25
30
35
40
Rain
fall (
mm
)
Co
ncen
trati
on
(m
g/l)
Date
Total Suspended Solids at SP1 October 2013 - March 2014 including rainfall
TSS Action Limit Target Limit Composite Rainfall
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Page 1
0
5
10
15
20
25
30
35
40
Co
ncen
trati
on
(m
g/l)
Date
Total Suspended Solids at SP1 October 2013 - March 2014 without rainfall
TSS Action Limit Target Limit Composite
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Appendix C
Section I.2.2 - Discharge of
uncontaminated surface water
runoff to drainage ditch (SW2).
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I.2.2 Discharge of uncontaminated surface water runoff to drainage ditch (SW2)
1.2.2.1 Receiving Environment
Uncontaminated surface water runoff from the Terminal will be discharged into a drainage
ditch (D 16) which runs along the R3 14 road. The drainage ditch feeds into the Muingingaun
River which is a tributary of Bellanaboy River which ultimately discharges into Carrowmore
Lake. Carrowmore Lake is a Special Protection Area (SPA) and part of a larger, complex
Special Area of Conservation (SAC). It is also an important local amenity in terms of water
abstraction, angling and scenic quality.
I.2.2.2 Surface Water Quality Monitoring Results
SEPIL commissioned Wood Environmental Management Ltd (WEML) to carry out chemical
and biological surface water quality monitoring on a number of local watercourses. Among
the watercourses monitored were the drainage ditch D16, the Muingingaun River, the
Bellanaboy River, and Carrowmore Lake. Water quality monitoring was carried out on a
monthly basis over the period June 2001 to May 2002. The monitoring results are detailed in
a report by WEML included in Attachment I.2 and summarised in the following section.
None of the watercourses or rivers in the area are designated salmonid rivers in the European
Communities (Quality of Salmonid Water) Regulations, 1988 but water quality can be
assessed by comparing the monitoring results to the limit values in the Regulations. Some
exceedances of limit values for pH, dissolved oxygen, temperature, suspended solids,
ammonium and nitrite were recorded for each of the above watercourses.
The monitoring results were also compared against the European Communities (Drinking
Water) Regulations, 2000. None of the watercourses are used for abstraction of drinking
water but a number of them flow into Carrowmore Lake which is used as a source of drinking
water. The monitoring indicated some exceedances of the limit values for pH and ammonium
for each of the above watercourses.
The average phosphate levels recorded in the watercourses indicate that a quality rating (Q
Index) ranging of 44 to Q5 (unpolluted) would be assigned to the watercourses based on the
Water Pollution Act, 1977 (Water Quality Standards for Phosphorus) Regulations, 1998.
(Note: This rating is based solely on phosphate levels and doesn’t take into account biological
monitoring results).
Macroinvertebrate sampling and analysis was undertaken at sampling locations on the
Bellanaboy and Muingingaun rivers. On the basis of the macroinvertebrate sampling the
rivers were assigned quality (Q-value) ratings. Due to environmental conditions and seasonal
changes the Q-value index for the rivers varied during the sampling year. The Q-rating of the
Bellanaboy river ranged from 43 to 44 (Moderately Polluted to Unpolluted) while the Q-
rating for the Muingingaun river was in general 43-4 (Slightly Polluted).
Suspended solids, nutrients, chlorophyll and water transparency levels were monitored in
Carrowmore Lake over the course of the year. Relatively low levels of suspended solids were
recorded in the lake. The levels of other parameters recorded indicated the trophic status of
the lake to be Mesotrophic / Eutrophic.
In summary the results of the water quality monitoring of the watercourses in the vicinity of
the Terminal indicate the watercourses to be slightly to moderately polluted based on the Q-
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value rating system. There are a number of potential sources of pollution in the catchment
area including agriculture, forestry, cutaway bogs and septic tanks which could all impact on
the water quality.
1.2.2.3 Assessment of Impact
Surface water runoff discharged from non-process areas of the Terminal will be
uncontaminated and therefore should not have any significant impact on the receiving
watercourses. The surface water collection and treatment system (described in Section F. 1.2)
has been designed to handle extreme rainfall events and will conduct the surface water runoff
from the site to the existing watercourse with minimum disturbance to the existing hydrology
of the area and will prevent the occurrence of flooding or polluting matter from entering the
watercourse.
The settlement ponds have been very conservatively designed and will provide buffering
storage capacity during high rainfall events and together with other measures incorporated
into the drainage system (e.g. “rip rap” outfalls) will assist in retarding flow velocity,
diffusing the water intensity and preventing scouring / erosion of existing watercourse.
The water to be discharged consists of uncontaminated surface water runoff. The discharge
water quality will be similar to or better than the existing surface water runoff quality from
the site. The settlement ponds are designed to reduce the levels of suspended solids to less
than 30 mg/l. This will be attained even during the worst case rainfall event
(l00-year 1 hour rainfall event of 31mrn) and therefore lower discharge levels of suspended
solids will be attained during more typical rainfall scenarios.
During operation of the Terminal it is unlikely that any oil could enter the uncontaminated
surface water drainage system. Nevertheless each settlement pond will incorporate an oil
skimmer as an added precaution. The Terminal perimeter drainage system will also
incorporate a 10m3 concrete tank. In the unlikely event of contaminated surface water
entering the perimeter drainage system it would be contained within this tank and pumped to
the Terminal treatment system for oily water (i.e. surface water runoff from process areas).
The quality of the surface water discharged will be monitored on a regular basis to ensure it
meets the required standard and that the settlement ponds continue to work effectively. The
drainage system and settlement ponds will be regularly inspected and maintained.
In summary, uncontaminated surface water from the Terminal will be discharged to a
drainage ditch in the vicinity of the Terminal which drains to a local watercourse. Water
quality monitoring indicates that the local watercourses are slightly to moderately polluted.
The Terminal site surface water collection and treatment system has been conservatively
designed. This will prevent any increased flooding risk of local watercourses and will ensure
that the quality of the surface water discharged is equal to or better than the quality of the
existing surface water runoff. Therefore the discharge of the uncontaminated surface water
from the Terminal to a local watercourse is not predicted to have any likely significant
adverse impact.
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Appendix D
Assessment of impact of
sediments in the discharge on the
shallow Carrowmore Lake.
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APPENDIX D
SEDIMENT CONTROLS PROPOSED AND DETAILS OF THEIR ACHIEVABLE PERFORMANCE AND LIMITS
1. OVERVIEW OF TERMINAL SURFACE WATER DRAINAGE SYSTEM Surface water is collected from the terminal footprint in an open channel drainage network. Surface water is collected from the landscaped peat areas, surrounding the terminal footprint, in a series of drainage ditches. The surface water from process areas, where it is at risk of becoming contaminated, does not enter these systems. Both the open channel system and the drainage ditch system have intermediate silt traps. The collected surface water passes through settlement ponds prior to discharge. The discharge is to the drain designated as D16, which discharges to the Muiningaun River. The Muiningaun River is a tributary of the Bellanaboy River, which flows into Carrowmore Lake.
2. SUSPENDED SOLIDS LOADING AND SURFACE WATER RUNOFF Suspended solids are entrained in surface water runoff as a result of a number of processes combined with the rainfall which generates a transport medium for the suspended solids. The primary erosion mechanisms are outlined in the following sections.
2.1 TERMINAL FOOTPRINT Suspended solids enter the terminal surface water runoff as a result of the following processes:
• general atmospheric deposition
• sediment loss from landscape areas
• wear from vehicle tyres
• deposition from vehicle exhausts
• sediment loss from roads & stones areas
CIRIA Document 609 Suspend Solids gives estimates of the potential suspended solids loading in surface water from various types of activities. Refer to Table 1 below.
SEPIL has undertaken monitoring of surface water at manhole 27 in the terminal footprint. Refer to Table 2 below.
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Table No.1 CIRIA Document 609 Suspended Solids Loading
CIRIA 609 - Sustainable Drainage Systems - Hydraulic, Structural & Water Quality Advice
Catchment Type Suspended Solids mg/L Mean 1st Quartile 3rd Quartile Urban Area 126.30 57.00 279.00 Industrial 50.40 18.10 140.00 Residential 85.10 37.60 192.50 Motorway 195.00 110.10 343.00 Main Roads 156.00 62.20 396.00
Table No.2 SEPIL 2014 Data from MH 27 (Discharge from Terminal Footprint)
Suspended Solids mg/L
Average Minimum Maximum Manhole 27 7.40 3.40 14.10
As can be seen from Table 1 and Table 2 above, the existing suspended solids concentration in the surface water from the terminal footprint is significantly lower than the estimated suspended solids concentration as noted in the CIRIA 609 Reference Document. The difference is mainly attributable to the sediment control measures that are present in the terminal. These are detailed in Section 2.2 below.
2.2 SEDIMENT CONTROL MEASURES - TERMINAL FOOTPRINT The concentration of suspended solids that enters the surface water runoff from the Terminal footprint has been minimised by the implementation of the following control measures on site:
• All surface water runoff from roads and hardstanding areas that discharge to the settlement ponds is collected in open drainage channels which have been constructed with minimum gradients which allow suspended solids to be retained within the channel for collection and removal off site.
• All surface water runoff from roads and hardstanding areas flow through a number of silt collection traps prior to discharging to the surface water drainage system which discharges to the settlement ponds.
• The use of vehicles within the terminal footprint is minimised thus preventing tyre wear etc.
• The use of vehicles within the terminal footprint is minimised which reduces the wear and tear on the roads and hard standing areas.
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• Large areas of the terminal footprint are stoned and are not likely to generate significant surface water runoff
• Open channels and silt traps are regularly cleaned by SEPIL maintenance staff.
The Met Eireann long term annual average rainfall for Belmullet, the nearest monitoring station, is 1.2448m per annum. The area of the terminal footprint contributing surface water run-off to the settlement ponds is 13.0844ha.
The suspended solids loading for the terminal has been calculated using both the CIRIA estimates and the SEPIL monitoring data and using the annual average rainfall value for the region. This information is presented in Table No. 3 below. The SEPIL data is considered more realistic, as it reflects the control measures present on site. The expected average suspended solids loading from the Terminal footprint is circa 1,205kg/Yr.
Table No.3 Suspended Solids Loading per year from Terminal Site ie within the Terminal Security Footprint
Suspended Solids kg/Yr Suspended Solids kg/Yr
Ciria 609 Reference Document
SEPIL 2014 SS Monitoring Data
Average 8,208.88 1,205.27 Min 2,948.03 553.77 Maximum 22,802.45 2,296.53
It should be noted that the above values are average readings and higher concentrations may be encountered during periods of heavy rainfall events.
2.3 REINSTATED LANDSCAPED PEAT AREAS Suspended solids enter the surface water runoff as a result of rainfall and overland flow disturbing the peat surface, resulting in erosion of the peat surface, which in turn generates suspended solids in the surface water runoff. The primary erosion mechanism is sediment erosion caused by rainfall and overland flow.
The quantification of the suspended solids concentration within the surface water runoff from the reinstated peat areas has been based on data on suspended solids in runoff from peat areas in the Erodibility of Hill Peat by Mulqueen et al; University of Ireland, Galway. This information is presented in Table No. 4 below.
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Table No.4 Suspended Solids Concentration Erodibility of Hill Peat; by Mulqueen et al; Nat. University of Ireland,
Galway Catchment Type Suspended Solids mg/L
The Leenane catchment in Co. Mayo has a ground cover of circa 70%
Sample No. 1 2.30 Sample No.2 4.20 Sample No. 3 3.40 Sample No. 4 5.00 Sample No. 5 3.40 Sample No. 6 4.30 Average 3.77
2.4 SEDIMENT CONTROL MEASURES – REINSTATED LANDSCAPED PEAT
AREAS The concentration of suspended solids that enters the surface water runoff from the reinstated peat areas will be minimised by the implementation of the following mitigation measures on site:
• Provision of vegetation cover to 100% of the reinstated peat areas.
• Provision of silt traps within any open channels in order to collect suspended solids.
• Open channels and silt traps being regularly maintained by SEPIL maintenance staff.
The area of the reinstated landscaped peat surrounding the terminal footprint is 125.92ha. The suspended solids loading from this area has been calculated using the above data on suspended solids in runoff and the annual average rainfall value for the region. This information is presented in Table No. 5 below. The expected average suspended solids loading from the reinstated landscaped peat areas shall be circa 5,904kg/year.
For the duration of the landscaping and peat areas reinstatement activities, which are currently underway on site, further sediment control measures are being implemented.
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Table No.5 Suspended Solids Loading per year from the Peat Reinstated Areas of the Corrib Site Suspended Solids kg/year
Erodibility of Hill Peat; by Mulqueen et al; Nat. University of Ireland, Galway
Min 3,605.01 Average 5,903.86 Maximum 7,836.99
3. SETTLEMENT PONDS The existing surface water settlement ponds were designed to control sediment in the runoff during the construction phase of the project. During this phase there were large areas of bare soil and peat exposed to potential erosion, peat and soil was being handled on site, and there were potentially significantly larger flow rates and suspended solids concentrations in the runoff. The settlement ponds will be retained in use during the permanent phase.
Using the settlement ponds will ensure that there is additional control of suspended solids from the surface water runoff from the terminal footprint and the reinstated landscaped peat areas.
Table No 6 below presents the combined suspended solids loading entering the settlement ponds from the terminal footprint and the reinstated landscaped peat areas, quantified as described above.
Table No.6: Total Suspended Solids Loading to Settlement Ponds Kg/Yr Average Concentration mg/L
7,109.14 4.11
Based on a suspended solids removal rate in the settlement ponds of circa 50%, and the calculated total flow of 1,730,272m3 per year, the expected average suspended solids concentration in the outflow from the settlement ponds will be circa 2.05mg/L.
Table No.6: Total Suspended Solids Loading discharged from the Settlement Ponds based on 50% Treatment efficiency
Kg/Yr Average Concentration mg/L
3,554.57 2.05
It should be noted that the above value is the average and much higher concentrations may be encountered during periods of heavy rainfall and/or routine maintenance of the reinstated landscaped peat areas.
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4. ASSESSMENT OF THE IMPACT ON CARROWMORE LAKE OF THE SEDIMENTS IN THE DISCHARGE
4.1 ASSESSMENT METHODOLOGY Carrowmore Lake is 960ha in area with several rivers and numerous streams entering it. The assessment estimates the quantity of additional sediment entering Carrowmore Lake yearly from the terminal footprint and adjacent landscaped peat areas. The resultant increase in the concentration of the suspended solids in the lake is calculated. The significance of the increase is assessed with reference to the European Communities (Quality of Salmonid Waters) Regulations, 1988, limit for suspended solids. Carrowmore Lake suspended solids monitoring Mayo County Council undertakes suspended solids monitoring of Carrowmore Lake. Results of recent monitoring are tabulated below.
Date Number of samples
Average mg/l
Maximum mg/l
Minimum mg/l
1/1/2013 to 6/3/2013 10 14 45 <5 13/3/2013 to 9/4/2013 5 10 19 <5 17/4//2013 to 18/6/2013 9 8 26 <5 27/6/2013 to 4/9/2013 11 7 24 <5 10/9/2013 to 31/10/2013 8 9 15 <5 1/11/2013 to 31/12/2013 8 7 9 <5 January and February 2014
2 6 7 <5
Source: Mayo County Council’s website http://www.mayococo.ie/en/News/CorribGasDevelopment/CorribGasTerminalDevelopment/MinutesofMonitoringCommitteeMeetings/AssociatedReports/
4.2 IMPACT ASSESSMENT The area of Carrowmore Lake is 960ha = 9,600,000m2. The maximum depth is approximately 2.5m. A conservative assumption is that the volume of water in the lake is 9.6x106 x 2.5 / 2 = 1.2 x 107m3. It is assumed that the maximum concentration of suspended solids in the discharge from the terminal settlement ponds is 30mg/l and the average concentration is 2.05mg/l. Refer to section 3 above for the quantification of the average suspended solids concentration in the discharge from the settlement ponds. The calculated annual volume of run-off from the terminal footprint and landscaped peat areas, based on Met Eireann long term rainfall data, is 1,730,272m3. The total sediment in this run-off is estimated at 3555kg/year. This load will increase the concentration of sediment in Carrowmore Lake by:
3,555 x 106 ÷ 12,000,000 x 103 = 0.296mg/l.
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0.296mg/l is circa 1% of the Salmonid Regulations limit for suspended solids, which is 25mg/l. As the suspended solids concentration in the lake is well below 25mg/l, an increase of this magnitude is not significant.
5.0 CONCLUSIONS
It is estimated that the total sediment run-off from the terminal footprint will be 3,555kg/year. This load will increase the concentration of sediment in Carrowmore Lake by 0.296mg/l. This value is approximately 1% of the Salmonid Regulations limit for suspended solids. As the suspended solids concentration in the lake is well below 25mg/l, an increase of this magnitude is not significant.
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Appendix E
Bellanaboy Bridge Gas Terminal
– Updated Operational Noise
Emissions Models
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REPORT 7648.140128.ENMrev03
BELLANABOY BRIDGE GAS TERMINAL
CORRIB GAS TERMINAL NOISE
EMISSIONS MODEL
OPERATIONAL NOISE EMISSIONS MODELS
Prepared: April 2014
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CONTENTS
1. Introduction 1
2. Noise Modelling Methodolgy 1
2.1 Meteorological Conditions 2
2.2 Calculation Assumptions 2
2.3 Operation Scenarios 2
2.4 Flaring Scenarios 2
2.5 Ground Flare 3
3. Calculation Results 4
3.1 Operational Noise 4
3.2 Further Site Sources 5
3.3 Flare Noise 5
4. Conclusions 6
List of Attachments
Figure 1 Operational Daytime Noise Contour
Figure 2 Operational Night-Time Noise Contour
Figure 3 Flare Noise Contour – Terminal Blowdown
Figure 4 Flare Noise Contour – Offshore Pipeline Depressurisation
Figure 5 Flare Noise Contour – Onshore Pipeline Depressurisation
Figure 6 Flare Noise Contour – Plant Start-up (worst case)
Figure 7 Flare Noise Contour – Compressor Purge (Cold Vent)
Figure 8 Height Contour and Identified Evergreen Foliage Areas
Figure 9 NSL Identification and Location
Appendix A Source Power Levels
Appendix B Partial Receiver Levels – Operational Noise
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BELLANABOY BRIDGE GAS TERMINAL
Operational Noise Emission Models Page 1 of 6
1. INTRODUCTION
The purpose of the modelling report is to accompany Shell E&P Ireland Ltd's application
for a review of the Industrial Emissions licence (EPA ref. no_0738-01) for the Bellanaboy
Bridge Gas Terminal site.
The report includes the most up=to-date design information as a result of detailed design
work since 2004. Detailed information on the model inputs is contained in Table A,
attached. The noise models presented in this report were developed afresh in 2010 from
plot layouts and input data made available by the engineering designer (AMEC), and this
has replaced the previous (pre-2004) noise emissions models for the site.
The revised modelling incorporates design changes and equipment updates that have
taken since the 2004 IPPC licence application, and which includes the addition of Waste
Heat Recovery on the gas compressor turbines, Selective Catalytic Reduction and
additional ventilation to the power generation equipment, plus additional pumps
required to facilitate the discharge of treated produced water through spare cores in the
umbilical bundle serving the offshore wells. Process valve noise emissions have been fully
reviewed and there has been addition of a diaphragm pump serving a new methanol
pump lube oil supply.
2. NOISE MODELLING METHODOLGY
To calculate noise emissions from the proposed terminal site, noise propagation has been
calculated using ISO96131 algorithms implemented within the Datakustic software,
CadnaA. This allows meteorological, air absorption, ground absorption and topographical
effects to be considered in detail, enabling for field predictions of noise emissions to the
environment to be modelled with known precision.
Noise levels emitted from the site will be relatively constant with the majority of plant
items running continuously. Some items that run intermittently contribute less to the
overall noise levels, but may be likely to attract attention during start up and shut down.
All such plant items are assumed to run continuously to offset this effect, and provide a
robust assessment.
1
ISO 9613 Acoustics - Attenuation of sound during propagation outdoors - Part 1: Calculation of the absorption of sound by
the atmosphere and Part 2: General method of calculation.’
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Operational Noise Emission Models Page 2 of 6
2.1 Meteorological Conditions
The calculations have been undertaken assuming standard downwind propagation in all
directions, temperature and humidity were set to 10°C and 70% respectively.
Attenuation due to foliage has been included through the identified areas of evergreen
woodland only.
2.2 Calculation Assumptions
The majority of plant items have been modelled as point sources. Process valves and
associated pipe lengths have also been modelled as point sources for these far-field noise
emissions calculations. Area sources have been used for modelling noise emissions from
some buildings.
Where building walls have been modelled using point sources, the source has been
assumed to be in the centre of the wall.
Refer to Appendix A, attached for further details on the noise sources.
2.3 Operation Scenarios
The scenarios considered in this study are for daytime & evening (07:00-19:00 & 19:00-
23:00) and night-time (23:00-0700) operation.
Some emergency equipment has been included in the daytime and evening model to
allow for maintenance test runs. These items have been advised by AMEC and can be
identified in Appendix A, attached.
Items which are likely to be intermittently run for short periods have been assumed to be
running continuously. If the period could occur during the night-time, then continuous
operation has been assumed through the night-time period.
2.4 Flaring Scenarios
The different types of flaring scenarios have been considered in this assessment as a
separate exercise.
The flare sound power levels are determined from published empirical methods on the
basis of maximum gas flow rate, jet aerodynamics, density and calorific value of the
constituent gas. Noise levels are initially steady at the stated maximum level as the
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Operational Noise Emission Models Page 3 of 6
maximum flow rate is maintained, followed by decrease as the remainder of the gas
volume is released. The sound power levels detailed below are based upon the peak flow
rate.
Scenario Peak Mass Flow Rate
kg/s
Sound Power Level
LwA dB
Terminal Blowdown 82 154
Offshore Pipeline Depressurisation 47 150
Onshore Pipeline Depressurisation 12 140
Plant Startup (Worst Case) 33 147
Compressor Purge (Cold Vent) <5 <86
Ground Flare (included in operational noise calculations)
2.5 106
Table 2.4 – Flare Source Data
The noise emissions from the flare tip have assumed to be omni-directional for all cases.
In reality there is expected to be a degree of directionality which would result in slightly
lower imission levels at nearby properties, especially during cold venting. This is therefore
considered to represent a robust assessment.
2.5 Ground Flare
Use of the maintenance ground flare was previously considered as a separate scenario in
the previous noise assessments. The most recent estimation of the ground flare sound
power level, which takes into consideration the surrounding shroud and up to date
technical information, is 106dB LWA at the maximum 2.5kg/s mass flow rate.
Information is now also available on the spectral content of the ground flare as a noise
source, enabling frequency dependant screening and air absorption losses to be included
in the noise propagation model, enabling a more realistic prediction than those previously
based only on geometric dispersion losses.
Although the process is designed for daytime and evening use only, operation of the
ground flare would be theoretically possible during the night-time.
This has therefore now been included in the operational noise calculations as a
continuous source running during all periods, however, it has also been included in this
summary of flare scenarios for clarity.
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3. CALCULATION RESULTS
3.1 Operational Noise
The results of the noise models are illustrated graphically in the noise map plots in the
attached figures. Partial levels at the nearest noise sensitive location (NSL) to the south
(No. 6) are shown in Appendix B, to establish the contribution from each plant item.
All nearby noise sensitive locations previously identified have been included. The
locations are detailed in Figure 9, attached. For the operational noise contours, only the
very nearest locations have been illustrated in the figures.
The calculated levels at the nearest NSL’s are summarised below for daytime, evening and
night-time scenarios, including the relevant noise ELVs set in the existing licenceand EPA
Noise Guidance Note (NG4) for comparison. Levels at the boundary of the site footprint
are also included.
NSL ID LAeq,T Coordinates
Daytime Evening* Night-time X Y
(dBA) (dBA) (dBA) (m) (m)
Emission Limit Values 45 40 35 - -
1 32.2 32.2 31.5 85609 332096
2 31.5 31.5 30.9 85740 332158
3 34.7 34.7 34.2 86206 332355
4 34.7 34.7 34.2 86217 332374
5 34.5 34.5 34.2 86297 332454
6 33.4 33.4 32.9 86329 332504
7 33.6 33.6 33.3 86269 332442
8 31.5 31.5 31.0 86072 331945
9 31.1 31.1 30.5 86054 331890
10 30.8 30.8 30.2 86025 331861
11 29.8 29.8 29.3 85991 331736
12 30.4 30.4 29.8 86003 331813
13 25.1 25.1 24.2 87261 331219
14 30.9 30.9 29.8 85033 332199
15 28.1 28.1 27.0 85350 334488
16 29.9 29.9 28.8 85535 334368
17 31.5 31.5 30.2 85845 334413
18 31.0 31.0 29.5 85875 334514
19 28.1 28.1 27.2 85498 334487
20 31.2 31.2 30.0 85816 334430
21 26.5 26.5 25.7 88494 334171
22 25.8 25.8 25.0 88612 334248
23 25.1 25.1 242 88666 334239
24 24.2 24.2 23.1 88704 334227
25 25.1 25.1 24.3 88777 334244
Table 3.1 – Predicted Operational Noise Levels
*Evening (1900-2300) has been included in line with EPA’s revised Noise Guidance Note (NG4). Operation and maintenance scenarios for this period have been assumed to be the same as daytime (0700-1900) to provide a robust assessment. Operationally, however, it is likely that less maintenance activity would be conducted during the evening period, providing an increased compliance margin.
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Operational Noise Emission Models Page 5 of 6
3.2 Further Site Sources
As well as the main noise producing items identified throughout the design and
assessment processes, the contribution of many other lesser noise sources has been
included with the detailed information now available for the less significant, but
contributory, systems which must still be borne in mind in the implementation of future
engineering design changes to ensure that the overall noise emissions criterion is met.
Any such items, in combination, would need to contribute less than 29dB(A) at the
nearest NSL’s for the site to comply with the ELVs and this should be treated as the final
noise budget against which to assess any remaining or proposed sources.
3.3 Flare Noise
Noise contour plots for each flare scenario are shown in the attached figures and receiver
levels at the nearest NSL, No.6 (approximately 615m from the flare stack), are
summarised below.
These levels are the peak LAeq levels which would occur when the flare is operating at the
maximum flow rates. The maximum initial flow rate would occur for a typical duration
indicated in the table below. After this, it would reduce to below 50% of the peak flow
rate, resulting in reduced noise emissions.
Scenario Level at nearest NSL (no. 6) LAeq,T
Duration of Flow
Duration above 50% of Peak Flow rate
Terminal Blowdown 83 dB 15 minutes 9 minutes
Offshore Pipeline Depressurisation1
79 dB 16 hours 5 hours
Onshore Pipeline Depressurisation1
69 dB 5.5 hours 3 hours
Plant Startup (Worst Case) 76 dB 1 hour 1 hour
Compressor Purge (Cold Vent) <14 dB 10 minutes 5 minutes
Cold venting of Stopped Compressor during compressor changeovers
14 dB 8 minutes 3 minutes
Table 3.3 – Predicted Flare Noise Levels 1The indicated duration is based on the inventory of the proposed onshore pipeline route, minor deviations in the route will result in
minor changes to the duration of the event, however it should not change the resulting noise levels
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Operational Noise Emission Models Page 6 of 6
4. CONCLUSIONS
Based on the most up to date information on the Terminal design, the calculations
undertaken demonstrate that when operational the Terminal is capable of meeting the
Industrial Emissions licence and EPA NG4 noise limits, providing provision is made during
final design and installation to ensure that the number of small sources such as valves and
piping are controlled to be within their allocated noise budget.
Noise levels at the nearest noise sensitive locations have been calculated for differing
operational and flaring scenarios during daytime, evening and night-time. The predicted
noise levels for each scenario have also been presented as noise contour plots.
CLARKE SAUNDERS ASSOCIATES
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FIGURES
Noise Contour Plots
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Figure 1: Operational Daytime Noise Contour
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Figure 2: Operational Night-Time Noise Contour
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Figure 3: Flare Noise Contour – Terminal Blowdown
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Figure 4: Flare Noise Contour – Offshore Pipeline Depressurisation
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Figure 5: Flare Noise Contour – Onshore Pipeline Depressurisation
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Figure 6: Flare Noise Contour – Plant Start-up (worst case)
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Figure 7: Flare Noise Contour – Compressor Purge (Cold Vent)
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Figure 8: Height Contour and Identified Evergreen Foliage Areas
Ground Height (m)
Foliage
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Figure 9: NSL Identification and Location
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APPENDIX A.1 - Point Sources
Name ID
Lw X Y Z
(dBA) (m) (m) (m) (m)
GPB Generation Cell Hot Inlet B1_FD10 75.6 On 5.4 r 86506 332981.4 37.4
GPB Generation Cell Hot Inlet B1_FD9 75.6 On 5.4 r 86482.2 332968.2 37.4
GPB Generation Extract EF1 B1_HV_EF1 86.4 On 6.4 r 86491.4 332956.9 38.4
GPB Generation Extract EF3 B1_HV_EF3 77.6 On 7.4 r 86494.4 332958.1 39.4
GPB Generation Extract SF1 B1_HV_SF1 78.6 On 7.4 r 86508.5 332965.9 39.4
GPB Generation Extract SF3 B1_HV_SF3 69.6 On 7.4 r 86500.8 332961.7 39.4
GPB HVAC Room South Wall B1X10SWall 59.4 On 9.4 r 86501.1 332962.2 41.4
GPB HVAC Room West Wall B1X14WWal 55.6 On 7.9 r 86487.1 332959.3 39.9
GPB HVAC Room Roof B1X4_Roof 63.6 On 10.9 r 86499.2 332965.5 42.9
GPB Switch Room - East Wall B1X7EWall 51.8 On 4.4 r 86511.1 332972.2 36.4
GPB HVAC Room - East Wall B1X8_EWall 55.6 On 9.8 r 86511.3 332971.8 41.8
GPB Switch Room - West Room B1X8WWal 51.8 On 3.4 r 86487.5 332958.7 35.4
GPB Switch Room - South Wall B1X9_SWall 57.8 On 4.4 r 86500.6 332961.9 36.4
SGC Building - Main Access B2_D1 77.4 On 2.9 r 86483.52 333190.88 34.9
SGC Building - HVAC Room B2HV_Ewall 67.9 On 5.4 r 86470.9 333193.1 37.4
SGC Building - HVAC Room B2HV_Roof 68.9 On 7.4 r 86468.1 333190.8 39.4
SGC Building - HVAC Room B2HV_Wwall 69 On 5.4 r 86464.86 333190.66 37.4
SGC Building - HVAC Extract B2HVACextr 92.2 On 2.9 r 86465.9 333184.5 34.9
SGC Building - HVAC Supply B2HVACin 87.7 On 2.9 r 86470.7 333198.5 34.9
Local Equipment Room Supply SF5 B99_HV_EF5 86.5 On 5.2 r 86511.5 333090.9 37.2
Local Equipment Room Extract EF5 B99_HV_SF5 79.5 On 1.9 r 86508.4 333096.5 33.9
SGC A - Suction KO Drum D2009A 82.6 On 4.9 r 86474.5 333155.8 36.9
SGC A - Gas Turbine Oil Cooler E2002A 87.4 On 3.9 r 86466.5 333180.1 35.9
S/G COMP.LUBE OIL COOLER E-2008A 97.8 On 33.7 a 86469.62 333177 33.7
CONDENSATE COOLER E-3002 94.9 On 46.9 a 86495.21 333156.05 46.9
LP GAS COMP. AFTERCOOLER E-3003A 97.8 On 36.52 a 86471.81 333129.94 36.52
HEATING MED. DUMP COOLER E-5001 96.8 On 33.7 a 86552.08 333174.11 33.7
Generator C Mixture Cooler E8801C 79.1 On 3.9 r 86481.4 332982.7 35.9
Generator C Jacket Cooler E8805C 83.3 On 3.9 r 86484.7 332979.8 35.9
TRANSFORNER 'A' ETR-320A 95.8 On 34.49 a 86503.93 333079.92 34.49
TRANSFORMER 'B' ETR-320B 95.8 On 34.49 a 86499.56 333077.49 34.49
FWPHExhaust FWPHex 110.3 Off 8 r 86435.88 332911.07 40
FWPHExhaust FWPHex 110.3 Off 8 r 86440.73 332913.69 40
Generator B Exhaust G8801B 86.2 On 15.9 r 86488.1 332978.1 47.9
Generator C Exhaust G8801C 86.2 On 15.9 r 86480.7 332974 47.9
Emergency Generator Enclosure G8802_encl 101.9 Off 2.9 r 86508.4 332988.6 34.9
Emergency Generator Exhaust G8802_Exh 103.2 Off 4.9 r 86511.1 332983.7 36.9
SGC Turbine A Intake K2002A__X1 83.9 On 6.9 r 86474.1 333193.5 38.9
SGC Turbine A Exhaust K2002A_X2 85.9 On 20.9 r 86481.7 333179.9 52.9
SGC Turbine A Ventilation K2002A_X4 78.3 On 3.9 r 86475.3 333189.4 35.9
Backwash Air Blower K8301 86.9 On 2.1 r 86446.7 333072.1 34.1
OFFSHORE TERMINATION UNIT N-1010 97.2 On 33.7 a 86231.53 333061.36 33.7
ODOURISATION PACKAGE N-2002 97.2 On 33.55 a 86299.02 332940.12 33.55
METHANOL STILL SCALE INHIBITOR N-4001 95.8 On 33.7 a 86324.21 333093.06 33.7
GROUND FLARE N8111 105.9 On 34.8 a 86554.59 333042.17 34.8
OIL SKIMMER N-8303 97.2 On 33.6 a 86451.51 333036.03 33.6
Air Package N-8501 89.8 On 8 r 86507.99 332929.93 40
NITROGEN PACKAGE N-8601A 90.2 On 33.7 a 86513.9 332940.6 33.7
Chlorination Package N8902 84.2 On 2.1 r 86525.5 332939.2 34.1
CORROSION INHIBITOR PACKAGE N-9001 97.2 On 33.7 a 86236.37 333066.55 33.7
CONDENSATE LOADING PUMP P-3001A 86.4 On 34.01 a 86350.28 333073.56 34.01
LP CONDENSATE PUMP P-3002B 85.7 On 34.02 a 86346.21 333080.9 34.02
CONDENSATE TRANSFER PUMP P-3004A 83.7 On 34.3 a 86491.12 333145.22 34.3
OFFSPEC CONDENSATE PUMP P-3005 85.7 On 34.02 a 86340.78 333090.7 34.02
METHANOL FEED PUMP P-4001A 85.7 On 34.02 a 86336.32 333067.65 34.02
WASTE WATER PUMP P-4002A 81.4 On 34.06 a 86501.66 333151.06 34.06
METHANOL REFLUX PUMP P-4003A 82.7 On 34.06 a 86517.26 333145.61 34.06
W/HEAD METH INJ PUMP P-4004 90.2 Off 33.7 a 86275.45 333069.12 33.7
W/HEAD METH INJ PUMP P-4005A 95.2 On 33.7 a 86276.78 333066.71 33.7
W/HEAD METH INJ PUMP P-4006A 84.2 On 33.7 a 86280.05 333060.81 33.7
METHANOL EXPORT BOOSTER PUMP P-4009A 82.9 On 34.02 a 86372.01 333034.15 34.02
HEATING MEDIUM TRAMSFER PUMP P-5001 88.2 On 34.13 a 86561.1 333172.24 34.13
HEATING MEDIUM CIRC. PUMP P-5002A 93.5 On 34.22 a 86558.23 333182.05 34.22
PRODUCED WATER CPI FEED PUMP P6001A 85.9 On 2.1 r 86446.3 333072.9 34.1
SAND FILTER FEED PUMP P6004A 84.9 On 2.1 r 86455.6 333079.1 34.1
TREATED PROD WATER SUMP PUMP P-6005A 82.1 On 33.63 a 86458.15 333053.2 33.63
Oil Transfer Pump P-6007 79.2 On 34.4 a 86457.8 333070.8 34.4
UF Recirculation Pump P-6008 85.2 On 34.4 a 86453.93 333078.06 34.4
Lime Slurry Recirculation Pump P-6015A 86.2 On 34.4 a 86444.2 333073.6 34.4
TREATED PROD WATER INJECTION PUMP P-6025A 85.7 On 33.7 a 86252.84 333084.41 33.7
TREATED PROD WATER INJECTION PUMP P-6026A 85.7 On 33.7 a 86250.83 333082.34 33.7
CLOSED DRAINS DRUM PUMP P-8201A 90.2 On 30.9 a 86456.6 333041.8 30.9
HEATING MED. CLOSED DRAIN PUMP P-8202 81.1 On 34.06 a 86540.19 333170.25 34.06
ROAD DRAINAGE SUMP PUMP P-8203 84.2 On 30.05 a 86819.73 333053.27 30.05
CLOSED DRAIN DRUM SUMP PUMP P-8204 74.2 On 28.63 a 86460.93 333046.74 28.63
DRAIN WATER SUMP PUMP P-8205A 77.3 On 33.58 a 86403.68 332849.19 33.58
TREATED WATER SUMP PUMP P-8301A 88.2 On 33.63 a 86479.6 333035.7 33.63
TREATED PROD WATER BOOSTER PUMP P-8302A 77.3 On 33.6 a 86456.2 333045.72 33.6
OIL SUMP PUMP P-8303 83.7 On 33.7 a 86479.6 333035.7 33.7
FIREWATER TRANSFER PUMP P-8304 95.2 On 33.63 a 86478.11 333017.61 33.63
MULTIMEDIA FILTER FEED PUMP P-8305A 90.2 On 33.98 a 86471.79 333047.16 33.98
SURFACE WATER TPS FEED PUMP P-8306A 97.2 On 33.63 a 86475.69 333021.98 33.63
SURFACE WATER PUMP 'A' P-8307A 87.2 On 33.95 a 86465.2 333060.68 33.95
PRODUCED WATER PUMP P-8308 75.2 On 34.4 a 86446.3 333072.9 34.4
FIREWATER TRANSFER PUMP P-8314 95.2 Off 33.63 a 86478.62 333016.69 33.63
FIREWATER PUMP P-8701A 102.2 Off 33.13 a 86440.48 332904.43 33.13
FIREWATER JOCKEY PUMP P-8702A 95.3 On 33.01 a 86443.64 332908.18 33.01
FIREWATER JOCKEY PUMP P-8702B 95.3 On 33.01 a 86458.51 332916.42 33.01
FIRE WATER SUMP PUMP P-8703 97.2 On 32.51 a 86445.84 332924.38 32.51
DIESEL DISTRIBUTION PUMP P-8801 79.1 On 33.55 a 86491.1 332933.53 33.55
UREA SOLUTION TRANSFER PUMPS P-8811A/B 97.2 On 33.92 a 86467.42 332968.3 33.92
POTABLE WATER PUMP P-8901A 97.2 On 33.7 a 86528.03 332948.89 33.7
APPENDIX A - SOURCE POWER LEVELS
Result. PWL Height Coordinates
Night time status
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SERVICE WATER PUMP P-8902A 97.2 On 33.7 a 86520.95 332946.34 33.7
FV-3005 V&P 80.4 On 34 a 86410.15 333045.93 34
PV-3079 V&P 86 On 34 a 86473.1 333132.04 34
PV-3029 V&P 86 On 34 a 86471.7 333131.26 34
LV-1016 V&P 75.3 On 47.5 a 86469.78 333144.83 47.5
FV-1005 V&P 84 On 47.4 a 86467.94 333143.82 47.4
FV-4010 V&P 90 On 34.5 a 86250.27 333064.77 34.5
FV-4011 V&P 89 On 34.5 a 86249.69 333065.82 34.5
FV-4012 V&P 89 On 34.5 a 86249.11 333066.87 34.5
FV-4013 V&P 89 On 34.5 a 86248.52 333067.92 34.5
LV-1006 V&P 76.3 On 34.1 a 86455.22 333165.22 34.1
PV-1009 V&P 86 On 39.7 a 86452.25 333170.68 39.7
PV-1021 V&P 79.7 On 34.6 a 86234.39 333051.96 34.6
PV-1038 V&P 84.8 On 39.7 a 86451.2 333170.1 39.7
PV-4021 V&P 79.3 On 34.2 a 86273 333067.08 34.2
PV-4026A V&P 79.3 On 34.2 a 86274.84 333063.76 34.2
PV-4033 V&P 79.3 On 34.2 a 86278.04 333057.98 34.2
FV-8701 V&P 76.9 On 33.6 a 86436.81 332905.43 33.6
FV-8702 V&P 91 On 33.6 a 86444.25 332909.55 33.6
FV-8703 V&P 90 On 33.6 a 86451.68 332913.68 33.6
FV-8704 V&P 76.3 On 33.6 a 86459.12 332917.8 33.6
FV-4008 V&P 91 On 34 a 86507.57 333157.1 34
FV-4009 V&P 95.4 On 34 a 86509.14 333157.97 34
FV-4014 V&P 91 On 33.8 a 86332.45 333072.25 33.8
LV-3002B V&P 90 On 34 a 86518.84 333155.11 34
LV-3009 V&P 88 On 34 a 86462.04 333146.83 34
LV-4008A V&P 90 On 34.1 a 86484.17 333131.77 34.1
LV-4008B V&P 74.3 On 34.1 a 86483.68 333131.58 34.1
LV-4016 V&P 90 On 34.1 a 86501.97 333144.58 34.1
PV-3005B V&P 88 On 34.1 a 86472.96 333128.99 34.1
PV-3005C V&P 74.3 On 34.1 a 86474.36 333129.77 34.1
PV-4013B V&P 74.3 On 34 a 86515.79 333161.65 34
PV-4042A V&P 77.9 On 34 a 86495.88 333149.59 34
PV-4042B V&P 76.9 On 34 a 86495.32 333149.27 34
PV-5001A V&P 58 On 59.5 a 86545.36 333179 59.5
PV-5001B V&P 83 On 59.5 a 86544.26 333178.47 59.5
PV-8116 V&P 77.9 On 42.5 a 86526.18 333041.64 42.5
PV-8407 V&P 71.7 On 47.5 a 86536.48 333171.98 47.5
PV-8505 V&P 81.6 On 33.9 a 86498.13 332941.48 33.9
PV-3002B V&P 74.3 On 33.9 a 86535.16 333168.16 33.9
PV-3005A2 V&P 76.3 On 47.6 a 86478.68 333140.74 47.6
PV-4001A2 V&P 89.8 On 34 a 86481.93 333139 34
PV-4001B2 V&P 77.9 On 34 a 86483.39 333136.37 34
PV-8603 V&P 76.9 On 33.9 a 86514.73 332944.74 33.9
LV-3002A V&P 77.9 On 34 a 86518.27 333154.91 34
PV-3002A V&P 92 On 33.9 a 86518.17 333158.4 33.9
PV-3005A1 V&P 88 On 47.6 a 86479.17 333140.67 47.6
PV-4001A1 V&P 94 On 34 a 86482.18 333139.36 34
PV-4001B1 V&P 90 On 34.1 a 86483.78 333136.48 34.1
PV-4013A V&P 77.7 On 34 a 86511.16 333159.08 34
PV-4026B V&P 88 On 34.2 a 86273.79 333063.17 34.2
PV-3022A V&P 82.4 On 44.4 a 86358.35 333109.09 44.4
PV-3022B V&P 82.4 On 44.4 a 86359.09 333108.66 44.4
PV-3037A V&P 91 On 44.4 a 86375.4 333078.33 44.4
PV-3037B V&P 91 On 44.4 a 86374.66 333078.54 44.4
PV-3039A V&P 82.4 On 44.4 a 86367 333093.12 44.4
PV-3039B V&P 82.4 On 44.4 a 86366.28 333093.31 44.4
PV-4064A V&P 90 On 44.4 a 86324.8 333035.96 44.4
PV-4064B V&P 90 On 44.4 a 86324.62 333034.97 44.4
PV-4066A V&P 91 On 44.4 a 86313.07 333056.58 44.4
PV-4066B V&P 91 On 44.4 a 86312.88 333055.33 44.4
PV-4068A V&P 77.4 On 44.4 a 86301.69 333077.09 44.4
PV-4068B V&P 77.4 On 44.4 a 86301.38 333075.63 44.4
PV-4070A V&P 90 On 44.4 a 86393.62 333038.01 44.4
PV-4070B V&P 92 On 44.4 a 86394.05 333038.25 44.4
PV-4072A V&P 85 On 44.4 a 86386.62 333051.66 44.4
PV-4072B V&P 85 On 44.4 a 86386.03 333051.34 44.4
FV-1004A V&P 93.5 On 47 a 86474.98 333141.35 47
TV-5005 V&P 69.7 On 34 a 86547.28 333179.11 34
PV-9003 V&P 67.7 On 34.7 a 86235.91 333067.78 34.7
HV-1010 V&P 78 On 47.3 a 86276.66 333060.88 47.3
HV-2001 V&P 84 On 47.5 a 86281.22 333051.82 47.5
HV-2002 V&P 69.7 On 47.2 a 86277.7 333050.29 47.2
LV-1002 V&P 78 On 34.1 a 86447.72 333162.34 34.1
LV-2010 V&P 83 On 33.9 a 86523.71 333191.31 33.9
PV-2010 V&P 83 On 41.5 a 86532.27 333199.37 41.5
PV-2011 V&P 83 On 41.5 a 86529.46 333194.96 41.5
PV-8401 V&P 87.1 On 34 a 86523.57 333165.97 34
PV-8408 V&P 84.8 On 34 a 86524.3 333164.66 34
FV-3004 V&P 83 On 33.8 a 86335.79 333101.08 33.8
FV-4005 V&P 80.7 On 34 a 86507.69 333148.02 34
FV-4007 V&P 81.7 On 34.1 a 86512.11 333146.01 34.1
FV-4018 V&P 79.3 On 52.1 a 86502.67 333149.23 52.1
LV-2002 V&P 79.3 On 34 a 86475.68 333153.37 34
LV-2052 V&P 83 On 34 a 86520.2 333178.05 34
LV-3004 V&P 81.7 On 33.9 a 86519.76 333156.76 33.9
LV-4001 V&P 81.7 On 34 a 86488.43 333135.74 34
PV-8405 V&P 81.7 On 34 a 86532.02 333170.54 34
PV-8406 V&P 83.7 On 34 a 86532.75 333169.22 34
PV-8905 V&P 85.8 On 33.8 a 86528.78 332943.72 33.8
TV-3002B V&P 81.8 On 34 a 86515.58 333152.96 34
LV-8901 V&P 89.8 On 33.8 a 86525.6 332946.99 33.8
TV-2014 V&P 81.8 On 34 a 86516.8 333190.57 34
TV-3002A V&P 81.8 On 34 a 86516.04 333152.76 34
LV-2006 V&P 81.8 On 34 a 86522.71 333187.33 34
FV-2054 V&P 82.8 On 47.5 a 86502.47 333168.56 47.5
FV-2004 V&P 82.8 On 47.5 a 86491.1 333162.26 47.5
FV-4027 V&P 82.8 On 35.8 a 86252.88 333065.42 35.8
FV-4028 V&P 88 On 35.8 a 86251.96 333067.08 35.8
FV-4029 V&P 86 On 35.8 a 86251.38 333068.13 35.8
FV-4030 V&P 87 On 35.8 a 86250.7 333069.37 35.8
FV-4031 V&P 91 On 35.8 a 86250.17 333070.39 35.8
LV-2017 V&P 85 On 34.1 a 86525.81 333212.21 34.1
LV-2021 V&P 87 On 34.5 a 86525.55 333207.44 34.5
Generator B Mixture Cooler E8801B 79.1 On 3.9 r 86489.8 332987.4 35.9
Generator B Jacket Cooler E8805B 83.3 On 3.9 r 86492.2 332983.9 35.9
Diaphragm Pump P4011 88.2 On 1 r 86277.87 333063.78 33
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APPENDIX A.2 - Area Sources
Name ID Result. PWL Result. PWL'' Night time status
Lw Lw''
(dBA) (dBA)
LP Gas Comp Roof LPCASR 86.3 73.6 On
Waste Water Building Roof WWBR 82.2 58.7 On
Sales Gas Roof B2 98.8 70.3 On
Sales Gas Aftercooler E2005 99.8 79.3 On
Methanol E4002 94.9 79.3 On
Firewater Building Roof Fire 91.8 67.1 Off
Gen Building Roof B1X1R 81.7 56.9 On
LP COMPRESSOR SUC LPCOMPSUC 94.2 84.8 On
LP Comp Casing Wall LPCOMPW 86.5 73.5 On
LP Comp Casing Wall LPCASW 86.5 73.5 On
Lp Comp Discharge LPCOMPDIS 94.2 84.8 On
Waste Water Building Walls WWBW 87.6 58.7 On
Sales Gas Building Walls B2 101.8 70.3 On
FIREWATER BUILDING WALLS Fire 94.8 67.1 Off
FIREWATER DOOR Fire 89.7 77.1 Off
Gen Building East Wall B1X1EW 100 81.7 On
Gen Building North Wall B1X1NW 103.5 81.4 On
Gen Building West Wall B1X1WW 81.7 63.4 On
Gen Building Door B1X1D2 87.4 76 On
Gen Building Door B1X1D2 87.4 76 On
Gen Building Louvre B1X1L1 87.5 87.4 On
Gen Building Louvre B1X1L1 87.5 87.4 On
APPENDIX A - SOURCE POWER LEVELS
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APPENDIX B - PARTIAL RECEIVER LEVELS
APPENDIX B.1 - Partial Levels at Worst Case Receiver (3)
Receiver Level dB(A)
Source Name ID Day Night
TOTAL LEVEL 34.7 34.2
Sales Gas Roof B2 23.8 23.8
Sales Gas Building Walls B2 23.8 23.8
ODOURISATION PACKAGE N-2002 22.3 22.3
LP GAS COMP. AFTERCOOLER E-3003A 21.5 21.5
GROUND FLARE N8111 20.7 20.7
Gen Building North Wall B1X1NW 20.1 20.1
OFFSHORE TERMINATION UNIT N-1010 19.7 19.7
CORROSION INHIBITOR PACKAGE N-9001 19.7 19.7
TRANSFORMER 'B' ETR-320B 19.4 19.4
FIREWATER BUILDING Fire 19
FIREWATER BUILDING Fire 19
LP COMPRESSOR SUC LPCOMPSUC 18.9 18.9
HEATING MED. DUMP COOLER E-5001 18.4 18.4
W/HEAD METH INJ PUMP P-4005A 18 18
Sales Gas Aftercooler E2005 17.7 17.7
TRANSFORNER 'A' ETR-320A 17.4 17.4
Gen Building East Wall B1X1EW 17.2 17.2
FV-4009 V&P 15.7 15.7
FWPHExhaust FWPHex 15.6
FV-1004A V&P 15.1 15.1
SURFACE WATER TPS FEED PUMP P-8306A 15 15
OIL SKIMMER N-8303 14.8 14.8
PV-4070B V&P 14.7 14.7
FWPHExhaust FWPHex 14.5
PV-4066A V&P 13.7 13.7
PV-4066B V&P 13.7 13.7
FV-4031 V&P 13.6 13.6
PV-3037A V&P 13.3 13.3
PV-3037B V&P 13.3 13.3
Emergency Generator Exhaust G8802_Exh 13.1
W/HEAD METH INJ PUMP P-4004 12.9
PV-4064A V&P 12.9 12.9
PV-4064B V&P 12.9 12.9
CONDENSATE COOLER E-3002 12.8 12.8
FV-4010 V&P 12.7 12.7
PV-4070A V&P 12.7 12.7
Methanol E4002 12.6 12.6
HEATING MEDIUM CIRC. PUMP P-5002A 12.3 12.3
FV-4008 V&P 11.8 11.8
FV-4011 V&P 11.6 11.6
FV-4012 V&P 11.6 11.6
FV-4013 V&P 11.6 11.6
PV-4001A1 V&P 11.3 11.3
S/G COMP.LUBE OIL COOLER E-2008A 11.2 11.2
MULTIMEDIA FILTER FEED PUMP P-8305A 11.1 11.1
LV-4008A V&P 11.1 11.1
LP Gas Comp Roof LPCASR 11.1 11.1
LP Comp Casing Wall LPCOMPW 11.1 11.1
LV-4016 V&P 11 11
PV-3002A V&P 10.9 10.9
Diaphragm Pump P4011 10.9 10.9
POTABLE WATER PUMP P-8901A 10.8 10.8
PV-4026B V&P 10.7 10.7
FV-4028 V&P 10.7 10.7
Generator C Exhaust G8801C 10.5 10.5
SERVICE WATER PUMP P-8902A 10.5 10.5
Generator B Exhaust G8801B 10.4 10.4
Waste Water Building Walls WWBW 10.1 10.1
Gen Building West Wall B1X1WW 9.9 9.9
FV-4030 V&P 9.6 9.6
Lp Comp Discharge LPCOMPDIS 9.6 9.6
SGC Turbine A Exhaust K2002A_X2 9.4 9.4
Backwash Air Blower K8301 9.3 9.3
PV-3005A1 V&P 9.1 9.1
LV-3002B V&P 8.8 8.8
CONDENSATE LOADING PUMP P-3001A 8.7 8.7
TREATED PROD WATER INJECTION PUMP P-6025A 8.7 8.7
TREATED PROD WATER INJECTION PUMP P-6026A 8.7 8.7
FIREWATER TRANSFER PUMP P-8304 8.7 8.7
FV-4029 V&P 8.7 8.7
FIREWATER TRANSFER PUMP P-8314 8.6
PV-1009 V&P 8.1 8.1
FIREWATER DOOR Fire 8.1
SURFACE WATER PUMP 'A' P-8307A 7.9 7.9
Waste Water Building Roof WWBR 7.9 7.9
Gen Building Roof B1X1R 7.9 7.9
PV-4072A V&P 7.6 7.6
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PV-4072B V&P 7.6 7.6
LV-2021 V&P 7.4 7.4
SAND FILTER FEED PUMP P6004A 7.3 7.3
TREATED WATER SUMP PUMP P-8301A 7.2 7.2
PV-4001A2 V&P 7.2 7.2
W/HEAD METH INJ PUMP P-4006A 7.1 7.1
SGC A - Gas Turbine Oil Cooler E2002A 7 7
PV-3029 V&P 6.9 6.9
PV-4001B1 V&P 6.9 6.9
Local Equipment Room Supply SF5 B99_HV_EF5 6.8 6.8
Emergency Generator Enclosure G8802_encl 6.8
HEATING MEDIUM TRAMSFER PUMP P-5001 6.8 6.8
PV-3079 V&P 6.8 6.8
HV-2001 V&P 6.7 6.7
PV-8401 V&P 6.6 6.6
GPB Generation Extract EF1 B1_HV_EF1 6 6
UF Recirculation Pump P-6008 6 6
METHANOL STILL SCALE INHIBITOR N-4001 5.7 5.7
LV-2017 V&P 5.3 5.3
FV-1005 V&P 5.2 5.2
Air Package N-8501 5 5
PV-1038 V&P 5 5
LV-8901 V&P 5 5
CONDENSATE TRANSFER PUMP P-3004A 4.9 4.9
GPB Generation Extract SF1 B1_HV_SF1 4.7 4.7
PV-3005B V&P 4.6 4.6
FV-4027 V&P 4.6 4.6
METHANOL EXPORT BOOSTER PUMP P-4009A 4.4 4.4
UREA SOLUTION TRANSFER PUMPS P-8811A/B 4 4
PV-2010 V&P 3.5 3.5
PV-2011 V&P 3.5 3.5
GPB Generation Extract EF3 B1_HV_EF3 3.3 3.3
PV-8406 V&P 3.1 3.1
NITROGEN PACKAGE N-8601A 3 3
LV-4001 V&P 2.9 2.9
OIL SUMP PUMP P-8303 2.7 2.7
PV-8408 V&P 2.7 2.7
FV-2004 V&P 2.7 2.7
LV-2010 V&P 2.6 2.6
FV-2054 V&P 2.6 2.6
PV-1021 V&P 2.5 2.5
LV-2052 V&P 2.5 2.5
TREATED PROD WATER SUMP PUMP P-6005A 2.4 2.4
PV-4033 V&P 2.4 2.4
PV-4026A V&P 2.3 2.3
PV-4021 V&P 2.2 2.2
SGC Building - HVAC Extract B2HVACextr 1.8 1.8
WASTE WATER PUMP P-4002A 1.8 1.8
PV-3039A V&P 1.4 1.4
PV-3039B V&P 1.4 1.4
PV-3022A V&P 1.2 1.2
PV-3022B V&P 1.2 1.2
TV-2014 V&P 1.2 1.2
PV-8405 V&P 1.1 1.1
LV-3004 V&P 0.7 0.7
FV-4014 V&P 0.6 0.6
HV-1010 V&P 0.6 0.6
FV-4007 V&P 0.5 0.5
GPB Generation Cell Hot Inlet B1_FD9 0.4 0.4
FV-4018 V&P 0.4 0.4
PV-8905 V&P 0.3 0.3
LP Comp Casing Wall LPCASW 0.3 0.3
LV-2006 V&P 0.2 0.2
Oil Transfer Pump P-6007 0 0
METHANOL REFLUX PUMP P-4003A -0.2 -0.2
FV-4005 V&P -0.3 -0.3
TV-3002B V&P -0.5 -0.5
TV-3002A V&P -0.5 -0.5
PV-5001B V&P -0.8 -0.8
FV-3005 V&P -0.9 -0.9
LV-1002 V&P -1 -1
HEATING MED. CLOSED DRAIN PUMP P-8202 -1.2 -1.2
SGC A - Suction KO Drum D2009A -1.3 -1.3
SGC Turbine A Intake K2002A__X1 -1.4 -1.4
LV-3009 V&P -1.5 -1.5
CLOSED DRAINS DRUM PUMP P-8201A -1.7 -1.7
Chlorination Package N8902 -1.9 -1.9
PV-4068A V&P -2.3 -2.3
PV-4068B V&P -2.3 -2.3
PV-8116 V&P -2.6 -2.6
ROAD DRAINAGE SUMP PUMP P-8203 -2.9 -2.9
SGC Building - HVAC Supply B2HVACin -3.1 -3.1
Gen Building Louvre B1X1L1 -3.1 -3.1
Generator C Mixture Cooler E8801C -3.2 -3.2
FIREWATER PUMP P-8701A -3.2
Gen Building Louvre B1X1L1 -3.3 -3.3
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Appendix F
Section E.2.2. Table E.6.
Summary of Proposed Discharge
to Surface Waters for points
SW1 and SW3
Attachment Table E.2 (i)
Emissions to Surface Water - for
points SW1 and SW3
Table I.2 (i) – Surface Water
Quality
Drawing E.2.1 Corrib
Bellanaboy Bridge Gas Terminal
Treated Water Discharge
Locations.
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Table E.6 Summary of Proposed Discharge to Surface Waters
Emission Emission Ref Proposed
Discharge
Location
Emission Sampling
Location Ref
Grid Reference Source/
Monitoring Point
Treated Surface Water Runoff (from process areas)
SW1 Sea outfall ca. 12.7 km offshore from landfall
location (no
change)
SW1-S 54° 19.72’ -09° 59.46’
Uncontaminated surface water runoff
from Terminal
SW2 R314 Road Drainage Ditch to south-
west of site (no change)
SW2-S 08598 E 332363 N (ING)
Treated Produced Water
SW3 65 km offshore at well manifold in sea
SW3-S 54° 20.34’ -11° 03.51’
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TABLE E.2(i): EMISSIONS TO SURFACE WATERS (One page for each emission)
Emission Point: SW3 Treated Produced Water
Emission Point Ref. No: SW3
Source of Emission: Treated Produced Water
Location of discharge : Corrib Manifold approximately 65km offshore (c 92.5km along the pipeline route from the Terminal)
Grid Ref. (12 digit, 6E,6N): 54º 20.34 '; -11º 03.51 ' (latitude and longitude co-ordinates are given due to offshore location)
Name of receiving waters and water body code:
Atlantic Ocean
Flow rate in receiving waters: Not applicable m3.sec-1 Dry Weather Flow
Not applicable m3.sec-1 95%ile flow
Available assimilative capacity:
Not available kg/day
Emission Details:
(i) Volume to be emitted
Normal/day 80 m3 Maximum/day 80 m3
Maximum rate/hour 3.33 m3
(ii) Period or periods during which emissions are made, or are to be made, including daily or seasonal variations (start-up /shutdown
to be included):
Periods of Emission (avg) 60 min/hr 24 hr/day 7 day/yr
80m
3/day maximum is proposed as a daily maximum discharge rate in the event it is possible to pump more water through the cores than the initial calculations suggest.
Actual discharge is likely to be in the region of 65m3/day.
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TABLE E.2(i): EMISSIONS TO SURFACE WATERS (One page for each emission)
Emission Point: SW1 Treated Surface Water from process areas
Emission Point Ref. No: SW1
Source of Emission: Treated Surface Water
Location of discharge : Outfall Pipe 12.7km offshore from landfall location
Grid Ref. (12 digit, 6E,6N): 54º 19.72 '; -09º 59.46 ' (latitude and longitude co-ordinates are given due to offshore location)
Name of receiving waters and water body code:
Atlantic Ocean
Flow rate in receiving waters: Not Applicable m3.sec-1 Dry Weather Flow
Not Applicable m3.sec-1 95%ile flow
Available assimilative capacity:
Not Available kg/day
Emission Details:
(i) Volume to be emitted
Normal/day 50 m3 Maximum/day 720 m3
Maximum rate/hour 30 m3
(ii) Period or periods during which emissions are made, or are to be made, including daily or seasonal variations (start-up
/shutdown to be included):
Periods of Emission (avg) 60 min/hr 24 hr/day 7 day/yr
80m3/day maximum is proposed as a daily maximum discharge rate in the event it is possible to pump more water through the cores than the initial calculations suggest.
Actual discharge is likely to be in the region of 65m3/day.
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Table I.2(i) SURFACE WATER QUALITY
(Sheet 1 of 2) Monitoring Point/ Grid Reference: SW1/ 085982, 332363
Parameter Results
(mg/l)
Sampling
method2
(grab, drift etc.)
Normal
Analytical
Range2
Analysis method
/ technique
2 Aug 2007
Surface
2 Aug 2007
Near –bottom (89m)
21/22 July 08
Surface
21/22 July 08
Near –bottom (92m)
pH
Temperature 15.77 12.14 13.98 11.44 CTD probe CTD probe
Electrical conductivity EC
Salinity 35.1 35.2 34.9 35.1 CTD probe CTD probe
Total Ammonia as N <0.01 µg/ <0.01 µg/ <0.01 µg/ 0.022 µg/ Water bottle
Chemical oxygen demand
Biochemical oxygen
demand
Dissolved oxygen DO
Orthophosphate as P
Nitrate as N
Nitrite as N
Calcium Ca
Cadmium Cd <0.0400 µg/l
<0.0400 µg/l <0.0400 µg/l <0.0400 µg/l Water bottle
Chromium Cr <0.500 µg/l <0.500 µg/l <0.500 µg/l <0.500 µg/l Water bottle
Chloride Cl
Copper Cu 2.450 µg/l 2.080 µg/l <0.200 µg/l 1.21 µg/l Water bottle
Iron Fe
Lead Pb 0.5450 µg/l 0.3890 µg/l 0.082 µg/l 40.8 µg/l Water bottle
Magnesium Mg
Manganese Mn
Mercury Hg <0.010 µg/l <0.010 µg/l <0.010 µg/l <0.010 µg/l Water bottle
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Surface Water Quality (Sheet 2 of 2)
Parameter Results
(mg/l)
Sampling
method
(grab, drift etc.)
Normal
Analytical Range
Analysis method
/ technique
2 Aug 2007
Surface
2 Aug 2007
Near –bottom (89m)
21/22 July 08
Surface
21/22 July 08
Near –bottom (92m)
Nickel Ni 1.100 µg/l 0.370 µg/l 0.350 µg/l 0.320 µg/l Water bottle
Potassium K
Sodium Na
Sulphate SO4
Zinc Zn 59.600 µg/l 5.900 µg/l 11.0 µg/l 8.72 µg/l Water bottle
Total alkalinity (as CaCO3)
Total organic carbon TOC
Total oxidised nitrogen
TON
Nitrite NO2
Nitrate NO3
Faecal coliforms (
/100mls)
Total coliforms ( /100mls)
Phosphate PO4
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Table I.2(i) SURFACE WATER QUALITY
(Sheet 1 of 2) Monitoring Point/ Grid Reference: SW3/ 54º 20.34 '; -11º 03.51 ' (latitude and longitude co-
ordinates are given due to offshore location)
Parameter Results
(mg/l)
Sampling
method2
(grab, drift etc.)
Normal
Analytical
Range2
Analysis method
/ technique
December 2013
Surface
December 2013
Bottom
pH
Temperature oC 11.7 10.5 CTD probe CTD probe
Electrical conductivity EC
Salinity CTD probe CTD probe
Total Ammonia as N <0.01 mg/l 0.01 mg/l Polypropylene
Chemical oxygen demand
Biochemical oxygen
demand
Dissolved oxygen DO
Orthophosphate as P
Nitrate as N
Nitrite as N
Calcium Ca
Cadmium Cd 0.039 µg/l <0.03 µg/l Polypropylene
Chromium Cr <0.5 µg/l <0.5 µg/l Polypropylene
Chloride Cl
Copper Cu 3.15 µg/l 0.28 µg/l Polypropylene
Iron Fe
Lead Pb 6.89 µg/l 0.201 µg/l Polypropylene
Magnesium Mg
Manganese Mn
Mercury Hg <0.01 µg/l <0.01 µg/l Water bottle
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Surface Water Quality (Sheet 2 of 2)
Parameter Results
(mg/l)
Sampling
method
(grab, drift etc.)
Normal
Analytical Range
Analysis method
/ technique
December 2013
Surface
December 2013
Bottom
Nickel Ni 0.585 µg/l <0.3 µg/l Water bottle
Potassium K
Sodium Na
Sulphate SO4
Zinc Zn Water bottle
Total alkalinity (as CaCO3)
Total organic carbon TOC
Total oxidised nitrogen
TON
Nitrite NO2
Nitrate NO3
Faecal coliforms (
/100mls)
Total coliforms ( /100mls)
Phosphate PO4
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689 1 A14 267 6
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As built location of outfall shown complies with condition 5.4 of IPPC licence (P073841)
MOTE: Onshore pipeline route under revision
Shell Explwation 8 Production in Europe Shell E & P Ireland {SEPIL)
CORRIB BELLANABOY BRIDGE
GAS TERMINAL TREATED WATER
DISCHARGE LOCATIONS
UTM 29U366174E6023193NWGS84 54o 20.34' -11o 03.51'
D (08.04.2014)
UTM 29U435553E6020540NWGS 84 54o 19.72' -09o 59.46'
Outfall - Treated Surface WaterDischarge Location - SW1
Corrib Manifold - Treated ProducedWater Discharge Location - SW3
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Appendix G
Non-Technical Summary
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NON-TECHNICAL SUMMARY
1.0 Introduction
1.1 General
Shell E&P Ireland Ltd. (SEPIL) is a member of the Royal Dutch Shell Group of
Companies.
The company operates Industrial Emissions Licence Register No. P0738-01
(previously Integrated Pollution Prevention and Control licence P0738-01) from the
EPA to process natural gas extracted from the Corrib Field for export to the Bord Gáis
transmission network from their Gas Terminal facility at Bellanaboy Bridge, Bellagelly
South, Co. Mayo.
SEPIL is applying to the agency for a review of the existing Industrial Emissions
Licence in respect of proposed changes to the activity, the treatment and monitoring
of emissions and the location of discharge points.
The changes to the activity which are described in this review application are as
follows:
Proposed change of discharge point for treated produced water from the
permitted outfall point just outside Broadhaven Bay, to the subsea manifold
located on the sea bed in the Corrib Gas Field in some 350m water depth. This
change followed discussions with the Erris Inshore Fishermans Association (EIFA)
in 2008, during which SEPIL agreed to change the location of the discharge of
treated produced water, subject to statutory approval.
Proposed inclusion of Selective Catalytic Reduction on the power generators to
meet the limits for Oxides of Nitrogen (NOx) specified in the existing Licence.
The locations of a number of sampling and monitoring points have been
reconciled to reflect their planned and as-constructed locations for the facility’s
operational phase. Where groundwater sampling boreholes have been moved
from their original proposed location this is to avoid pipelines or services or to
use suitable existing monitoring points. New locations have been
hydrogeologically assessed and are equivalent to or an improvement on previous
proposed locations.
Surface and groundwater drains are proposed to be monitored and controlled as
separate systems. This has been achieved by changing the Emergency Holding
Tank (EHT) design configuration. The revised design also incorporates
infrastructure as required by licence P0738-01.
It is proposed to amend the emission limit values (ELV) for suspended solids in
stormwater (rainwater) run-off from the site from 5 mg/l to 30 mg/l in
accordance with Best Available Techniques guidance.
Additional noise data from flare/ venting operations is presented.
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Modified firewater retention arrangements to comply with Condition 3.17 of
licence P0738-01. This was notified by submission (COR-01-SH-GE-1068) to the
OEE.
Updated location of septic tank and Puraflo modules. These have changed due to
ground conditions.
Proposed removal of ambient monitoring at the Erris Head outfall which is no
longer required as treated produced water discharge will no longer take place at
this location.
Proposed change to monitoring exhaust velocity from turbines from using an air
flow meter to calculation method.
Proposed transitional surface water arrangement during “backfeed gas”
commissioning until outfall pipe is available entailing the discharge of treated
surface water run off form process area to be routed from the treated surface
water treatment (Esmil) plant to local ditch via settlement ponds.
Licence P0738-01 required SEPIL to submit the scope of marine receiving
environmental surveys to the EPA. It also required SEPIL to submit details of
surveys to be carried out prior to commencement. SEPIL wishes to apply for a
change to the licence condition relating to this as part of this review application.
Requirements of the EU Industrial Emissions Directive (2010/75/EU) and the
Environmental Protection Agency (Industrial Emissions) (Licensing) Regulations
2013 S.I. 137 of 2013.
Details of monitoring systems put in place capable of demonstrating integrity and
water tightness on a continuous basis of any cores within the umbilical pipeline
used to convey process effluent.
Seveso classification of the site changed to “Upper tier”
This review also addresses the requirements of the EU Industrial Emissions
Directive (2010/75/EU) and the Environmental Protection Agency (Industrial
Emissions) (Licensing) Regulations 2013 (S.I. No. 137 of 2013).
1.2 Classes of Activity
The applicable classes of activity for the facility (the Terminal) under the First
Schedule of the Environmental Protection Agency Act, as amended, are:
Class 9.3.1 the operation of mineral oil and gas refineries
Class 2.1 Combustion of fuels in installations with a total rated thermal input
of 50MW or more
1.3 EIS and Planning Permission Documents
An Bord Pleanála granted planning permission (with conditions) for the Terminal on
22nd October 2004. Since then there have been a number of planning amendment
applications. Planning permission is in place for all the changes proposed in this
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application. The EIS prepared for the terminal planning application and subsequent
addenda and updates, the planning permission for the Terminal and subsequent
planning permission, amending the original permission, are submitted as part of this
application the application.
1.4 BAT Guidance
The processes used at the Terminal utilise ‘best available techniques’ (BAT) and will
be operated using ‘best available practice’. In particular, the technologies and
systems used to minimise and control emissions are considered BAT.
The following BAT guidance documents are relevant to the activity:
EPA Office of Environmental Enforcement (OEE) Guidance Note for Noise: Licence
Applications, Surveys and Assessments in Relation to Scheduled Activities (NG4).
EPA BAT Guidance Note on Best Available Techniques for the Oil and Gas Refining
Sector 2008.
EPA BAT Guidance Note on Best Available Techniques for the Energy Sector
(Large Combustion Plant Sector) 2008.
The following BREF documents are relevant to the activity:
Integrated Pollution Prevention and Control (IPPC) Reference Document on Best
Available Techniques for Mineral Oil and Gas Refineries February 2003.
Integrated Pollution Prevention and Control Reference Document on Best
Available Techniques for Large Combustion Plants July 2006.
Integrated Pollution Prevention and Control (IPPC) - Reference Document on Best
Available Techniques in Common Waste Water and Waste Gas
Treatment/Management Systems in the Chemical Sector – February 2003.
Integrated Pollution Prevention and Control (IPPC) Reference Document on the
General Principles of Monitoring July 2003.
Reference Document on Best Available Techniques for Energy Efficiency February
2009.
Integrated Pollution Prevention and Control Reference Document on Best
Available Techniques on Emissions from Storage July 2006.
No relevant BAT conclusions have been published.
1.6 Determination of Emission Limit Values
The emission limits for emissions to air from the gas turbines were determined by the
Large Combustion Plant Regulations, 2012.
The emission limits for emissions to air from the power generators (spark ignition
engines) were determined by Annex 5 of the Gothenburg Protocol and the BRef for
Large Combustion Plants.
The emission limits for emissions to surface water were determined by the EPA BAT
Guidance Note on Best Available Techniques for the Oil and Gas Refining and by the
previous licence.
The emission limits for noise emissions was determined by the EPA Guidance Note for
Noise: Licence Applications, Surveys and Assessments in Relation to Scheduled
Activities (NG4).
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1.7 European Communities (Control of major Accident Hazards Involving Dangerous
Substances) Regulations, 2006
The Terminal constitutes an establishment to which the European Communities (Control
of major Accident Hazards Involving Dangerous Substances) Regulations, 2006 (S.I.
No. 74 of 2006) applies. The product and raw methanol inventory exceeds the Lower
Tier threshold requirements for Articles 6 and 7 of the SEVESO II Directive, as such
classifying it as Upper Tier.
1.8 Derogation
No derogation is being sought.
2.0 Terminal Operations
2.1 General
The onshore Bellanaboy Bridge Gas Terminal will extract natural gas from the Corrib
Field for processing and treatment to Bord Gáis specifications prior to exporting to
the distribution network. The Terminal is designed to produce up to 9.9 million
standard cubic metres of natural gas per day from the Corrib Field. The Corrib Field
is a gas field located below the seabed in the Atlantic Ocean ca. 65km off the Mayo
coastline and at ca. 350 metres water depth.
The Terminal monitors and controls the operation of the entire Corrib Field facilities
(onshore Terminal, onshore pipeline) and offshore sub-sea facilities) such that gas
production meets demand and to ensure that operations are conducted in a safe and
environmentally sound manner. The Terminal is a 24-hour manned operation, 365
days per year, utilising a five shift system. At steady state operation, the total
number of personnel associated with the Gas Terminal will range from approximately
100 to120 personnel.
The primary functions of the Terminal will be to:
Monitor and control the operation of the entire Corrib Field facilities (onshore and
offshore) such that gas production meets demand and to ensure that operations
are conducted in a safe and environmentally sound manner.
Remove liquids from the Corrib gas stream so that it meets the Bord Gáis
network transmission specification.
Compress, meter and odourise the gas prior to export to the Bord Gáis
transmission network.
Recover the hydrocarbon condensate from the gas stream and export it off-site.
Inject methanol and corrosion inhibitor for use in the sub-sea facilities and
recover methanol for re-use.
Treat water removed from the natural gas stream and discharge the treated
water to sea.
2.2 Process Unit Operations, Utility and Treatment Systems and Safety Systems
The principal process unit operations at the Terminal and the utilities / ancillary
equipment including safety systems which will support these operations are outlined
in the following sections.
2.2.1 Process Unit Operations
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Inlet and Reception Facilities
The Inlet and Reception Facilities will receive the fluids from the Corrib Field and
remove entrained water and liquid hydrocarbons. The fluids from the Corrib Field
that are received at the Terminal will be mainly gas, but some liquid will also be
present. The liquids consist primarily of:
Aqueous Phase:
o Water of Condensation (present in the gaseous form within the Corrib Field
which condenses out from the gas as its temperature and pressure fall) and
Formation Water (present in the liquid form within the reservoir). Formation
Water, if it occurs, is only expected later in the field life. Water of
Condensation and Formation Water are referred to as Produced Water.
o Methanol (injected from the Terminal to prevent freezing in the sub-sea
equipment and pipeline).
o Corrosion inhibitor injected into the sub-sea system to prevent corrosion.
Liquid Hydrocarbon Phase:
o Condensate (hydrocarbons that exist in vapour phase in the gas reservoir
and condense from the gas as the temperature and pressure fall).
The production fluids will arrive at the Terminal generally as a very fine mist but with
intermittent “slugs” of liquids also arriving at the Terminal. 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 liquids build up at these low points,
it will be picked up by the fast-flowing gas and will arrive in varying quantities or
‘slugs’. If required, the build-up of liquids in the pipeline can be cleared by running a
sphere (known as a pig) through the pipeline.
On entry to the Terminal, the incoming fluids are passed through a slugcatcher. This
is an arrangement of large pipes in which the incoming production stream is calmed
by substantially reducing its velocity and the two liquid phases are separated from
the gas by gravity. The condensate and water/methanol that separate out from the
gas stream pass to the condensate and methanol recovery systems respectively. The
gas stream flows to the Inlet Separator which separates finer drops of liquid from the
gas stream before it passes to the gas conditioning stage.
Gas Conditioning
The Corrib Field gas can be considered a very pure gas and therefore the
conditioning required to meet export gas specification is very simple. The gas
conditioning process will firstly remove any trace mercury (if present) which will be
absorbed onto the removal bed and converted into a stable chemical compound. The
gas conditioning process will then dry the gas stream (by lowering the dew-point)
and remove any residual liquids. This is achieved by feeding the gas to a pressure-
letdown valve where it is allowed to expand. This has the effect of cooling the gas
and condensing out any remaining traces of condensate, methanol and water.
Gas Compression and Export
Before the conditioned gas stream can be exported to the transmission network it
will be compressed to the required export pressure by compressors which are
powered by gas turbines. The gas will then be metered and an odourant will be
added prior to export to the transmission network.
Condensate Recovery and Stabilisation
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Hydrocarbon condensate is as a byproduct of the gas treatment process. The
condensate recovered in the inlet and reception facilities, and conditioning stage will
be stabilised by a series of pressure reductions and heating. It is then cooled and
any trace mercury (if present) in the condensate stream will be removed by a
mercury removal bed and converted into a stable chemical compound in the process.
The condensate is then transferred to storage tanks prior to being exported off-site.
It is anticipated that the exported condensate will be used as a fuel and
consequently. Any gas flashed from the process will be used in the Low Pressure (LP)
Fuel Gas system.
Methanol Recovery, Regeneration and Chemical Injection
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. The methanol
recovered from the gas has a high water content and it is separated from the water
by distillation in the methanol still. Corrosion inhibitor will be injected into the
methanol system for transfer to the off-shore facilities to prevent corrosion in the
off-shore facilities.
2.2.2 Utilities and Treatment Systems
Fuel Gas System
Natural gas that is used as a fuel in the Terminal is referred to as Fuel Gas. The Fuel
Gas system will use some of the natural gas extracted from the Corrib Field as a fuel
supply for the Terminal operations. High Pressure (HP) fuel gas will be used as a fuel
in the sales gas compressor turbines. Low Pressure (LP) fuel gas will be used as a
fuel in the power generators.
Waste Heat Recovery and Heating Medium System
An aqueous solution of 40%wt Triethylene Glycol (TEG)/Water mixture is used as a
heating medium to provide heating to various Terminal process operations. The use
of a 40%wt TEG solution avoids potential freezing at minimum ambient temperature.
The heating medium is circulated through Waste Heat Recovery Units that are
attached to the exhaust ducts of the gas turbines. These units heat the heating
medium fluid. The requirement for waste heat recovery is a condition in the existing
Industrial Emissions licence (Condition 3.7). The heating medium fluid will then be
transferred to the process users (Inlet Heater, Cold Condensate Heater, Condensate
Heater, Methanol Reboiler).
Utility Gases
A nitrogen generation package will supply nitrogen to be used in blanketing / purging
of tanks, 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 Instrument Air Package will supply clean, dry, compressed air for
instrumentation and plant use (as required).
Potable and Service Water Systems
The local authority water supply (sourced from Carrowmore Lake) will undergo
treatment at the Terminal prior to use as a supply of potable water. The local
authority supply will also be used if necessary, for manual make-up of firewater in
the firewater pond.
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Power Generation
The Terminal will be self-sufficient in power generation. Three gas compression
engines (2 Duty/1 Standby) fuelled by low pressure fuel gas will generate power for
the Terminal. A diesel driven emergency generator will be used to provide
emergency power to critical users on loss of the normal power supply. Depending on
Operational and Commercial requirements, a small percentage of overall load will be
taken from the grid supply. The primary use of the grid supply is to provide a backup
power supply to the firewater transfer sumps.
Treatment of Produced Water
Produced water will be treated as described in the previous application and will be
discharged in line with the emission limit values set out in the existing licence.
As part of the recovery of natural gas from the reservoir, some fluids will also arise
in the form of water of condensation and formation water, which comes from the
rock reservoir in which the gas occurs. The condensed water often contains traces of
organic compounds and some metals. The formation water, should it occur will
contain natural salts and minerals which have leached from the rock in which the
water has been resident over geological time. The actual composition will vary from
location to location (well to well) and over time. Indications of the likely constituents
have been determined from industry experience and from the testing of the water
recovered from the exploration wells.
The water that is removed from the natural gas stream (referred to as produced
water) will be treated prior to discharge to sea. The majority of treated produced
water will be discharged through spare cores in the umbilical to the subsea manifold
located at the Corrib gas field some 65km offshore (~ 92km along the pipeline
length from the terminal) and in 350m depth of water. Any surplus treated produced
will be removed offsite by a licensed waste management contractor. To control
biological growth in the umbilical cores a small amount of biocide will be added to
the treated produced water prior to being discharged into the umbilical cores. The
biocide will be added for a period of 2 hours per day.
Annual usage of biocide will be less than 0.395m3. On discharge, produced water will
be rapidly diluted and dispersed and the chosen biocide will rapidly biodegrade and
undergo additional degradation via hydrolysis. Consequently the environmental
impact will be negligible.
The produced water treatment plant is a multi-stage treatment system, which
includes:
Corrugated Plate Interceptor,
Ultrafiltration,
Nano Filtration,
Granular Activated Carbon Bed,
Ion-Exchange Units,
pH adjustment.
Treatment of Surface Water Runoff (from process areas)
Rainwater falling on process areas included bunded areas on site will be collected in
the potentially contaminated drain system on site (oily water system). The water will
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be treated in the surface water treatment plant and will be discharged via the
permitted outfall located ca. 12.7 km offshore from the landfall location.
The surface water treatment plant is also a multi stage treatment system, which
includes:
Corrugated Plate Interceptor,
Multimedia Filter,
Ultrafiltration unit.
Both treatment systems will share common sludge treatment facilities (Precipitation,
Coagulation, Flocculation, Filter Press equipment).
Uncontaminated surface water and ground water
Rainwater that falls on non-process areas on site will be collected in the perimeter
surface water drain system. The water will be directed through the emergency
holding tank (EHT) where it is continuously monitored for Total Organic Carbon/Total
Carbon as a precautionary measure.
In the event of a confirmed fire or if contamination is detected, the isolation valve in
the EHT will automatically close thus preventing surface water from leaving the site.
Water can be returned to the open drain sump for treatment and disposal via the
permitted outfall.
2.2.3 Safety Systems
Flaring
Flare systems are provided at the Terminal for depressurisation of the plant for
maintenance purposes and during emergency situations. The ground Maintenance
Flare System will primarily be used to safely depressurise sections of the Terminal’s
gas systems for maintenance. During emergency situations, gas from high pressure
(HP) and low pressure (LP) sections of the plant can be flared through the HP and LP
flares respectively.
Firewater
The firewater system provides water for fire-fighting purposes and supplies water to
hydrants, monitors, deluge systems, foam systems and hose reels at the Terminal.
Firewater is stored in the Firewater Pond. The Used Firewater Pond will collect
potentially contaminated firewater in the event of a fire.
Nitrogen Blanketing
Nitrogen will be used in blanketing and purging of tanks, process vessels and
pipework for safety purposes.
Laboratory
There will be an on-site laboratory located within the main Terminal buildings
complex. The laboratory will be used for product quality and environmental testing
purposes and to assist with process troubleshooting if required. The laboratory will
contain required equipment to carry out these tests.
2.3 Fuel and Energy Consumption
There will be two principal users of gas fuel at the Terminal:
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Power Generators (2 Duty/1 Standby) firing on Natural Gas (Fuel Gas)
Sales Gas Compressor Turbines (Duty/Standby) firing on Natural Gas (Fuel Gas)
An emergency generator running on diesel will be used during emergencies or black-
starts. The terminal is connected to the ESB electrical grid. The original design of the
plant included a fired heater for heating the Plant Heating Medium. The Fired Heater
was designed to burn gas as the primary fuel as well as excess condensate not
exported off-site. This has been removed from the design and replaced with waste
heat recovery on the compressor gas turbines, with a consequent reduction in
CO2 emissions and improvement in overall plant energy efficiency.
2.4 Alternatives Considered
The following alternatives have been considered since granting of Licence Register
No. P0783-01:
Onshore Pipeline Routing: The onshore pipeline development was subject to a
review which commenced in 2007 and included the consideration of:
o alternative landfall points, pipeline routes, construction methods, and
o alternative options for the design and configuration of the Landfall Valve
Installation (LVI).
The review resulted in the selection of a new pipeline route between the
permitted landfall point and the terminal, as well as an update to the design of
the landfall valve.
Selection of Selective Catalytic Reduction to reduce NOx emissions: Following the
grant of Licence Register No. P0783-01 the conditions required that power
generation engine exhausts would be required to meet the 250mg/
Nm3 NOX Emission Limit Value (ELV). Alternative options to reduce the NOx level
in the exhaust gas were considered.
Five alternative options (set out in the table below) were identified and screened
for practicability, cost, impact and viability.
Alternative Options
Considered Description
1. Selective Catalytic
Reduction (SCR)
Retain the purchased gas engines and install an SCR
exhaust treatment package to reduce emitted NOx
below the ELV.
2. Convert Gas Engines with
connection to Electricity Grid
and use of an emergency
diesel generator
Convert the purchased gas engines to run at fixed
speed to achieve NOx emission level of 250 mg/Nm3
NOx with connection to the electricity grid to handle
plant load variations and procure an emergency
diesel generator-set to meet lower onsite power
requirement during grid outages.
3. Convert existing gas
engines with connection to
the Electricity Grid, during
outages only using
generators
Convert the purchased gas engines to run at fixed
speed to achieve NOx emission level of 250 mg/Nm3
NOx with connection to the grid to handle plant load
variations. Existing gas engines would be run during
grid outages.
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4. Connection to electricity
grid
Replace purchased gas engine generator sets with a
dual-redundant grid connection.
5. Procure other available
power generation
technology
Use alternative power generation arrangements, such
as gas turbines, Combined Heat and Power (CHP) or
renewable energy.
Of those alternatives considered as technically feasible and economically viable,
SCR was identified as the preferred option, as it is a proven method of reducing
NOx emissions and has been implemented on numerous gas engine applications
in the United States.
A design study confirmed the practicality of retro-fitting SCR systems to the gas
engine power generation units and achieve the required NOx emission reduction
levels with minimum changes to the terminal plant.
3.0 Raw Materials and Product
Natural gas will be the only ‘product’ of the Terminal. The Terminal will be designed
to produce 350 million standard cubic feet of (9.9 million cubic metres) of natural
gas per day from the Corrib field for export to the Bord Gáis distribution network. All
other materials at the Terminal will be either materials utilised in the operation of the
Terminal or by-products from the treatment of the natural gas.
The Corrib field contains a dry sweet (no hydrogen sulphide) gas with an expected
condensate yield of less than 0.5 barrels per million standard cubic feet (0.08 cubic
metres per 28,317 cubic metres).
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4.0 Emissions to Atmosphere
4.1 Emission Sources
The main emissions to atmosphere from the facility will be generated by two gas
turbines and three power generators as described below.
The two gas turbines are fitted with low NOx (Oxides of Nitrogen) emission
technology, to ensure compliance with the Emission Limit Values (ELVs) specified in
the existing Industrial Emissions Licence (P0738- 01).
The three power generators at the Terminal will be fuel gas fired compression
engines, which will be high efficiency ‘clean burn’ engines. Selective Catalytic
Reduction (SCR) will be used to minimise emissions of NOx to ensure the exhaust gas
complies with the Emission Limit Values (ELVs) specified in the existing IPPC licence
(P0738-01).
The Emergency Generator and Firewater Pump Engines will only be used for
emergency situations and testing regimes. This equipment will be fired on low
sulphur diesel, which will minimise emissions of SO2.
In emergency situations, to allow depressurisation of equipment for safety reasons,
it may be necessary to flare gas from the gas terminal using the high pressure (HP)
and low pressure (LP) flares. The HP/LP flares will also be used for testing during the
commissioning phase and thereafter only used in emergency situations.
Flaring results in the release of NOx and CO from natural gas combustion and also
unburnt hydrocarbons depending on the destruction efficiency of the flare. Emissions
to air of NOx and CO during flaring activity have been assessed in the dispersion
modelling study. Releases of unburnt hydrocarbons are negligibly low in quantity.
As part of normal operation, very occasionally, it will be necessary to cold vent gas
from certain high pressure and low pressure sections of the plant through the high
pressure (HP) and low pressure (LP) flare stacks respectively. The potential impacts
on air quality due to cold venting have also been assessed.
4.2 Fugitive Emissions
Fugitive emission sources are limited to minor leakages from connections, isolation
and control valves, relief valves, rotating equipment seals and analysers. This type of
emission is small but unavoidable in this type of installation. The Terminal has been
designed to minimise the number of potential sources of fugitive emissions by
minimising the numbers of components from which minor leakages could occur. The
use of low-leak equipment (valves, pumps, etc.) in the Terminal will further reduce
the potential for fugitive emissions as will good housekeeping practices, including
preventative maintenance and routine monitoring of equipment on site. Nitrogen
helium leak testing will be carried out prior to the introduction of hydrocarbons; this
will ensure fugitive emissions are kept to an absolute minimum level for all flanges
and shaft seals.
4.3 Assessment of Impact of Atmospheric Emissions
Operations at the Terminal will not result in a significant impact on local air quality.
This conclusion is based on a comparison of the ground level pollutant concentrations
predicted by highly conservative dispersion modelling with relevant air quality
standards and guidelines.
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The modelling predicts no relevant ambient air quality standard or guideline will be
exceeded or approached at any location beyond the site boundary when all installed
plant is operating at full output (a worst case scenario). Existing air quality is very
good and is predicted to remain so with the gas terminal in operation.
Emissions of the main polluting substances (as defined in the Schedule of EPA
(Industrial Emissions) (Licensing) Regulations 2013, (S.I. No. 137 of 2013)) to the
atmosphere are highly unlikely to impair the environment.
5.0 Emissions to Waters
5.1 General
There will be three discharge points to surface waters from the terminal as described
below:
Treated Surface water runoff from process areas which will be discharged at the
outfall outside Broadhaven Bay – SW1
Uncontaminated surface water runoff which will be discharged to the R314 Road
Drainage Ditch to south-west of Terminal – SW2
Treated Produced water which will be discharged at the subsea manifold via the
umbilical cores – SW3
The different sources of water and their associated drainage systems at the Terminal
have been segregated to minimise the unnecessary treatment of less contaminated /
uncontaminated systems. Treatment systems in place for produced water and
surface water runoff (from rainfall falling on process areas on site where there is
potential for the water to become contaminated ) comprise multi stage treatment
prior to discharge to sea to ensure compliance with the emission limit values set out
in Licence Register No. P0738-01. The produced water and surface water systems
will be treated in separate systems before being discharged at separate locations.
Treated produced water will be discharged to emission point SW3, while treated
surface water runoff will be discharged to emission point SW1, when this emission
point is available. Construction of the Corrib onshore pipeline and associated water
outfall pipeline to emission point SW1 is underway with construction estimated to be
completed by late 2014. Treated surface water will be discharged through emission
point SW2 from the storm water settlement ponds for the interim period as described
below. Multi stage treatment will be completed prior to discharge.
In advance of the completion of the outfall pipe to emission point SW1, it is proposed
to commission and test some sections of the plant, using gas from the Bord Gáis gas
grid. This transitional arrangement is referred to as “back-feed gas”. During back-
feed gas, treated surface water run-off from process areas, which will be discharged
to SW1 when the terminally will be fully operations, will be discharged to SW2. The
discharge will be monitored and will comply with the emission limits values for SW2.
Once discharge point SW1 becomes available, the treated surface water run-off from
process areas will be discharged through it.
Uncontaminated Surface Water (or “storm water”) comprises runoff from the
Terminal’s non-process areas and roofs. This Storm water is considered clean and is
collected in the perimeter surface water drains. These drains are routed via an
Emergency Holding Tank (EHT) to the settlement ponds prior to discharge a minor
water course in the vicinity of the Terminal at emission point SW2, which feeds into
the Bellanaboy River and ultimately Carrowmore Lake
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Storm water is monitored in the EHT as a precautionary measure. In the unlikely
event of contamination being detected the isolation valve will close preventing storm
water from leaving the site.
Groundwater is collected beneath the site to prevent the groundwater level rising
within the fill and to ensure a stable platform for the terminal. Groundwater is
directed to the perimeter groundwater drains and converges in groundwater manhole
26 (MH26)in the south west corner of the site. As a precautionary measure
groundwater is continuously monitored for TC/TOC (Total Carbon / Total Organic
Carbon).
In the unlikely event of contamination detected in the groundwater system at MH26
or in the surface water drains at the EHT, either system can be independently
isolated from discharging into the settlement ponds. Retained water from either
system can be pumped back to the Open Drain Sump for subsequent onsite
treatment. Maintaining the systems segregation of groundwater and surface water in
this way has the benefit of minimizing the quantity of water that would be required
to be managed and treated in the event of confirmed contamination.
Groundwater and surface water converge in manhole 27 and the combined flow is
conveyed to the settlement ponds.
The settlement ponds are as described in the previous application. The settlement
ponds will retain the oil retention barrier previously referred to as an oil skimmer as
an additional precautionary measure. The drainage system, including the settlement
ponds, has been very conservatively designed and will provide buffering storage
capacity during high rainfall events and will assist in retarding flow velocity, diffusing
the water discharge intensity and preventing scouring / erosion of the existing
watercourse. The water is sampled and monitored in accordance with the conditions
in the existing licence and discharged to the road drainage ditch, which feeds in to
the Bellanaboy River and ultimately Carrowmore Lake.
It is estimated that the total sediment run-off from the terminal footprint will
increase the concentration of sediment in Carrowmore Lake by 0.296mg/l. This value
is approximately 1% of the Salmonid Regulations limit for suspended solids. As the
suspended solids concentration in the lake is well below 25mg/l, an increase of this
magnitude is not significant.
5.2 Assessment of Impact of Emission to Waters
Treated Produced Water (SW3)
Due to the small volume and level of treatment of produced water, plus the dilution
and dispersion available at the discharge point and taking into account the rapid
biodegradation characteristics of the chosen biocide it is predicted that no observable
environmental impacts will occur due to the discharge in the Corrib Field at emission
point SW3.
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Treated Surface Water from Process Areas (SW1)
Previous dispersion modelling in support of the IPPC application in December 2004
assessed the impact of the combined treated produced water and surface water at
emission point SW1, the outfall outside Broadhaven Bay. These studies showed that
given the level of treatment the discharge would have a negligible impact on water
quality.
As produced water will now not be discharged via this outfall, the determination that
there would be negligible impact in this area is still valid. Moreover the potential for
impact would be reduced.
With respect to the discharge of uncontaminated surface and groundwater water
from the Terminal to a local watercourse in the vicinity of the Terminal (SW2), no
significant impact is anticipated. Biological monitoring undertaken Bellanaboy River
upstream and downstream of the site during earthworks construction stage at the
site indicated no impact to the surface water limit adopted. Therefore adopting a
similar limit for the operational phase suggests that water will be maintained in a
good status. No impact is anticipated to the Bellanaboy River or Carrowmore Lake.
6.0 Emissions to Ground
There is one emission point to ground at SL1 from the Terminal.
Domestic sewage consisting of wastewater from staff facilities (Toilets, Showers,
Canteen etc.) will be treated in a septic tank and Bord na Móna Puraflo system
before being discharged to a 300 m2 percolation area on site. The Puraflo system will
treat the effluent to a very high standard prior to discharge to the percolation area
where further polishing of the effluent can be expected to occur. The location of the
Puraflo system has been amended and was subject to a planning amendment
application.
Various containment measures (including bunding and kerbed areas) have been
incorporated into the design of the Terminal to contain any accidental releases and
so prevent impact on ground or groundwater quality.
The baseline report, prepared for the application, concludes that on the basis of the
site investigations undertaken it appears that the site is underlain by a layer of peat
overlying mineral soils (head and till) which in turn overlies weathered rock and
bedrock comprising dark grey metamorphic schist belonging to the Inverschist
formation. An aquifer vulnerability assessment of the site rated the aquifer beneath
the site as being a Poor Generally Unproductive Aquifer (Pu) based on Geological
Survey of Ireland (GSI) guidelines. Based on the thickness and type of overburden
cover, the aquifer vulnerability for the majority of the site (including the percolation
area and Terminal footprint) is considered moderate (M) using GSI Guidelines for
aquifer protection.
Taking into account the relatively small volume and the high standard of treated
effluent from the Puraflo system and that the fact that the underlying aquifer is
considered a Poor Aquifer with moderate vulnerability (majority of site), the
discharge of the treated effluent to the percolation area is not predicted to have any
significant adverse impact on the underlying soils, bedrock or hydrogeology at the
Terminal site.
7.0 Noise Emissions
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Noise emissions will comply with the limits set out in Industrial Emissions Licence
P0738-02.
The Terminal has been designed and built to comply with standards equal to the
more onerous standards required for an ‘Area of Low Background Noise’, as specified
in the EPA Guidance NG4. The minimisation of noise has been an integral part of the
Terminal design and noise level criteria have been specified for all equipment to
ensure that operation of the Terminal has minimal impact on any noise sensitive
receptors (e.g. residential dwellings) in the vicinity of the Terminal.
In addition to this the Terminal has been designed so there will be no tonal or
impulsive noise audible at noise sensitive locations.
There will be various noise generating equipment associated with the normal
operation of the Terminal. There will also be noise generating equipment which,
other than for testing purposes, will only be used in emergency situations (e.g.
emergency generator).
Environmental noise surveys have been carried out at the closest Noise Sensitive
Locations (NSLs) to the Terminal site in 2013, 2008, 2003, 2001 and 2000. Analysis
of this data demonstrates that weather strongly influences the soundscape of the
area. The modelling has shown that the noise contribution from the Terminal will not
exceed licensed limits.
A schedule of plant items with the potential to generate significant noise levels was
used as the basis for the Terminal noise emissions modelling presented in the 2003
Terminal EIS. This schedule has been maintained and updated with engineering
developments over the intervening period and reviewed. Noise modelling has been
updated to take into account site measurement data for the fire water pump house
and associated systems, and some of the more significant cooling fan systems which
could be run during full plant commissioning. A very detailed study of noise
emissions from process valves and pipework was also undertaken which resulted in a
programme of additional noise control lagging works to achieve demonstrable
compliance with noise limits.
A review was undertaken of noise emissions arising from all conceivable maintenance
and upset scenarios in which hydrocarbon inventory would need to be discharged
from the Terminal either by cold venting or flaring. The operation of the HP and LP
flares would cause the normal operational noise limits to be exceeded; however the
only times the HP/LP flares will operate will be for testing and thereafter only in
emergency situations. Therefore following commissioning the HP/LP flares will only
be used rarely.
Cold vented releases from compressor changeovers will be vented (not ignited)
through the HP flare, which is not anticipated to cause any noise disturbance and will
comply with the noise limits set out in the existing licence.
In summary the noise generated during normal operation of the Terminal is not
predicted to have any significant impact on ambient noise levels or noise sensitive
receptors in the vicinity of the Terminal.
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8.0 Waste
The Terminal will not generate significant quantities of waste. Minimisation of waste
was one of the criteria considered during the selection and design of
equipment/processes at the Terminal. No wastes will be accepted at the Terminal.
All waste generated on site, both hazardous and non-hazardous, will be handled,
stored, transported off-site and treated / disposed of in accordance with statutory
requirements and in a manner that will eliminate or minimise any risk to persons
and/or the environment. A dedicated waste storage area will be used to store waste
prior to its removal off-site.
The additional waste stream in this application comprises surplus treated produced
water and condensate which will be disposed of off-site using tankers.
A Waste Management Programme will be implemented during the operation of the
Terminal to ensure the proper management of waste on site which will focus on
reduction, recovery and recycling of wastes where feasible. The Programme will form
a key part of the formal Environmental Management System to be implemented on
the site.
9.0 Sampling and Monitoring
Shell E&P Ireland Ltd. (SEPIL) will comply with the emissions monitoring regime
specified by the Environmental Protection Agency as part of the Industrial Emissions
Licence.
Provision for monitoring, sampling and analyses of environmental emissions, has
been incorporated into the design of the Terminal. The Terminal will employ the
appropriate technology and control systems to ensure that all processes continue to
perform to specification and that any process upsets (e.g. environmental control
systems) are quickly detected and rectified. SEPIL propose a programme of
monitoring and sampling to ensure operations do not have any significant impact on
the environment.
The location of sampling and monitoring points has been updated in this review
application to reflect their planned and as-constructed locations for the facility’s
operational phase.
Monitoring has been provided for emissions to atmosphere, emissions to surface
waters and emissions to ground. In addition to this ambient monitoring will be
carried out on air quality, surface water quality, groundwater quality and a
continuous noise meter will be installed on the site in order to monitor noise levels
prevailing in the vicinity of the terminal.
Ambient monitoring of marine waters in the vicinity of SW1, outside Broadhaven
Bay, is no longer proposed as only treated rainwater falling on process areas on site
will be discharged at this location. The water will go through a very comprehensive
treatment process and will be discharged in line with the emission limit values set
out in the existing licence. Given the volume and level of treatment of discharge no
impact is anticipated.
Similarly ambient monitoring in the vicinity of the subsea manifold, in the vicinity of
SW3, is not proposed. Given the very small volume and high level of treatment of
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water discharged no observable environmental impact is anticipated from the
discharge.
As there are no predicted impacts in the vicinity of the facility it is not envisaged that
there will be any transboundary impacts and therefore no additional monitoring is
required.
10.0 Energy Efficiency
The Terminal will be self-sufficient in power generation with three power generators
(2 Duty / 1 Standby) each capable of supplying half the maximum power demand of
the Terminal. This system comprising individual power generation units and gas
turbines combined with waste heat recovery was chosen over alternative systems
because of the specific requirements of the Terminal and because it will require a
lower total thermal input and thus result in lower emissions to atmosphere.
The original design of the plant included a heater for the Plant Heating Medium,
which would use fuel gas as the primary fuel and hydrocarbon condensate when
available. A decision was made not to use condensate as fuel in the Terminal and
this led to a comprehensive review of the energy efficiency of the plant. The result of
this review was a decision to install Waste Heat Recovery (WHR) on the gas
compressor turbines. It is estimated that the WHR units installed in the exhausts of
the gas turbines will recover up to 5.5MW of heat energy, which is sufficient to meet
the design heat demand of the terminal.
It is estimated that WHR will save the combustion of approximately 0.65 MMscf
(million standard cubic feet) per day of fuel gas in the heating medium heater and
reduce CO2 emissions from the site by approximately 10,000 tonnes per year. Heat
integration solutions with a contribution up to 8 MW have already been included in
the current Corrib plant design to decrease process heat requirements.
The primary fuel used at the Terminal will be natural gas, which is a very clean fuel
and high efficiency combustion equipment will be employed at the Terminal. A load
management scheme will manage the operation of the three power generators and
will be designed to match load and demand thereby optimising energy supply.
Regular servicing and maintenance of equipment will ensure that all equipment
continues to perform to specification. Insulation has been incorporated into building
structures and equipment at the Terminal to minimise heat losses. An Energy
Management System including energy auditing and consumption reporting will form
part of the Environmental Management System (EMS) to be implemented at the
Terminal to ensure the ongoing efficient use of energy. Energy use and efficiency
within the Terminal will be benchmarked against similar installations and this will be
used as a driver for continual improvement.
11.0 Containment of Accidental Emissions
All surface water runoff from process areas and bunded areas of the Terminal which
could potentially be contaminated, will drain to the Open Drains Sump and will be
treated in the Surface Water Treatment System prior to discharge.
Bulk chemical and fuel storage tanks at the Terminal will be bunded to contain at
least 110% of the volume of the largest single tank or 25% of the volume of the
total tankage within the bund (whichever is greater). Valving exterior to the bund
wall(s) will isolate the bund contents to contain any spillages and to control the
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discharge from the bund(s) to the Open Drains Sump. Rainfall accumulation
procedures will be adopted to ensure the capacity of bunded areas are not reduced.
Dosing, injection and cleaning chemicals will be stored in small quantities and any
spillage will be contained locally in bunding or drip trays for re-use or disposal. Any
other potential sources of spillage (e.g. pumps, sample points, level gauges, etc.)
will be provided with local shelter and collection trays, sumps or interceptors as
appropriate.
A Major Accident Prevention Policy (MAPP) will be prepared for the site and
implemented by the Safety Management System at the Terminal. The MAPP will
include for the identification, evaluation and prevention of major accident hazards
and for emergency planning and emergency response to minimise the consequences
of any accidents on human health and the environment
12.0 Cessation of the Activity
The life of the Corrib Gas Field has been predicted by reservoir simulation and
modelling to be between 15 and 20 years. The Bellanaboy Bridge Gas Terminal has
a minimum (design) life of 30 years. Decommissioning of the Terminal is expected
to take place after 2032. The timing of decommissioning will be determined by the
volume of gas produced each year from the Corrib Field, which is primarily a function
of the volume of gas contained within the Corrib Field and how effectively and rapidly
the gas contained within the reservoir can be recovered.
The Petroleum Lease for the Corrib Field contains stringent provisions to ensure that
the Corrib Field facilities, including the Bellanaboy Bridge Gas Terminal, are
decommissioned in a timely and appropriate manner. A Decommissioning Plan will
be prepared to comply with this requirement.
SEPIL will ensure that appropriate measures are taken to avoid any pollution risk and
return the site to a satisfactory state.
13.0 Measures to Comply with Environmental Quality Standards
As described above, the terminal facilities, equipment, abatement systems and
operating procedures have been designed to comply with the relevant Environmental
Quality Standards. The monitoring, described above, will be undertaken to ensure
that compliance is achieved.
14.0 Measures to Comply with Council directives 80/68/EEC and
2006/118/EC in Relation to the Protection of Groundwater
As described above, the Terminal facilities, equipment, abatement systems and
operating procedures have been designed to ensure the protection of groundwater.
The monitoring, described above, will be undertaken to ensure that groundwater has
been protected.
15.0 Measures to Minimise Pollution over Long Distances or Outside of
Ireland
As described above, the Terminal facilities, equipment, abatement systems and
operating procedures have been designed to minimise pollution in the vicinity of the
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Terminal and outfalls. These facilities, systems and equipment will also serve to
minimise long distance pollution and pollution outside Ireland. No such pollution is
expected to occur.
13.0 Site Management and Control
SEPIL aligns its HSE policy with that of the corporate company.
An Environmental Management System (EMS) certified to the international standard
ISO:14001 will be implemented at the Terminal. This will provide a formal structure
for environmental management, ongoing assessment of environmental performance
and continual improvement at the Terminal. As part of the Health, Safety and
Environmental (HSE) Plan an EMS will be prepared which will detail the EMS targets
for the Terminal and how they will be achieved. Staff will be issued with a copy of
the plan, will familiarise themselves with the plan and will participate in
implementing the plan. To ensure commitment to meeting the targets in the plan,
EMS performance will form part of each person’s annual appraisal, with good
performance being rewarded accordingly.
The EMS will align with the corporate Shell requirements for HSE Management
Systems and specific procedures therein relating to environmental management
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Appendix H
Table E.1 (ii) Main Emissions to
Atmosphere
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TABLE E.1(ii) MAIN EMISSIONS TO ATMOSPHERE (1 Page for each emission point)
Emission Point Ref. No:
A2-4
Source of Emission:
Power Generator A
Location:
Utilities Area
Grid Ref. (12 digit, 6E,6N):
086481E; 332974N
Vent Details Diameter:
Height above Ground(m):
0.4m (Internal) 15.0m
Date of commencement:
2014
Characteristics of Emission:
(i) Volume to be emitted:
Average/day 204,762 Nm3/d Maximum/day 255,824 Nm3/d
Maximum rate/hour 10,659 Nm3/h Min efflux velocity 13.1 m.sec-1
(ii) Other factors
Temperature 550 oC (max) 470 oC(min) 500 oC(avg)
For Combustion Sources: Volume terms expressed as : wet. √ dry. ___5___%O2
(iii) Period or periods during which emissions are made, or are to be made, including daily or seasonal variations (start-up
/shutdown to be included):
Periods of Emission (avg) 60 min/hr 24 hr/day 365 day/yr (Generators A/B/C – 2 Duty / 1 Standby A)
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