Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report

APPENDIX 3 Offshore Facility Construction, Offshore Installation, Hook-Up and Commissioning and Offshore Operations - Supporting Assumptions for Atmospheric Emission calculations TABLE OF CONTENTS A3.1 Introduction 3 A3.2 Onshore fabrication of Offshore Platforms Including Jackets, Topsides and Drilling

Template 3 A3.2.1 Construction and Load-Out 3

A3.2.1.1 Methodology ........................................................................................... 3 A3.2.1.2 Pollutant Emission Factors ..................................................................... 4 A3.2.1.3 Topsides ................................................................................................. 4 A3.2.1.4 Emissions Data ....................................................................................... 5 A3.2.1.5 Jackets.................................................................................................... 6 A3.2.1.6 Emissions Data ....................................................................................... 6

A3.2.2 Installation and Hook-Up & Commissioning (HUC) 7 A3.2.2.1 Methodology ........................................................................................... 7 A3.2.2.2 DUQ and PCWU Jackets and Topsides, and Template......................... 7 A3.2.2.3 Emission Factors for vessels .................................................................. 7 A3.2.2.4 Emissions Data ....................................................................................... 8

A3.3 Subsea Water Injection development Facilities (Manifolds, WI Flowlines, Umbilicals) 8 A3.3.1 Installation, Tie-In and Hook-Up & Commissioning 8

A3.3.1.1 Methodology ........................................................................................... 8 A3.3.1.2 Emission Factors for vessels .................................................................. 8 A3.3.1.3 Assumptions ........................................................................................... 9 A3.3.1.4 Emissions Data ....................................................................................... 9

A3.4 Inter-Field Export Pipelines (Oil and Gas) 9 A3.4.1 Installation, tie-in and commissioning 9

A3.4.1.1 Methodology ........................................................................................... 9 A3.4.1.2 Emission Factors for vessels .................................................................. 9 A3.4.1.3 Assumptions ......................................................................................... 10 A3.4.1.4 Emissions Data ..................................................................................... 10

A3.5 MODU Pre-Drilling 11 A3.5.1 Methodology 11

A3.5.1.1 Emission Factors .................................................................................. 11 A3.5.1.2 Assumptions ......................................................................................... 11 A3.5.1.3 Emissions Data ..................................................................................... 12

A3.6 Offshore Facility Offshore Operation Including Start-Up 12 A3.6.1 Methodology 12

A3.6.1.1 Emission Factors .................................................................................. 13 A3.6.2 Emissions Data 13

A3.6.2.1 Combustion Emissions ......................................................................... 13 A3.6.2.2 Flaring emissions offshore.................................................................... 14 A3.6.2.3 Total emissions due to Offshore Operations ........................................ 15

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/1 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report

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31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/2 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report A3.1 Introduction The following sections present the atmospheric emissions and their derivation for the construction, installation, hook-up and commissioning (HUC), and operations phases of the ACG Phase 3 project offshore. It includes pollutant emission factors, general assumptions and emissions data for the various atmospheric emissions contributors for the previously mentioned phases of the offshore facilities including jackets, topsides, template, inter-field export pipelines, subsea systems, pre-drilling and Operations. Emissions are calculated using internationally accepted Emission Factors that are calculated based on real time data collected over time. The following sources of emission factors have been used to be able to calculate the emissions during construction using mobile equipment and diesel power generators; installation and hook up using seagoing vessels; operations including combustion and flaring: • Pollutant emission factors for general plant and equipment have been sourced from the

EMEP/CORINAIR Atmospheric Emission Inventory Guidebook, 3rd edition, October 2002, Technical Report No. 30;

• Pollutant emission factors for power generators have been sourced from the US EPA AP-42, Section 3.4. (Compilation of Air Pollutant Emission Factors, AP-42, Fifth Edition, Volume 1: Stationary Point and Area Sources; US EP, January 1995);

• Pollutant emission factors for sea-going vessels have been sourced from the E&P Forum Report No. 2.59/197 (Methods for Estimating Atmospheric Emissions from E&P Operations, Report No. 2.59/197; The Oil Industry International E&P Forum, September 1994); and

• Guidelines on Atmospheric Emissions Inventory; UK Offshore Operators association Ltd (UKOOA); July 1995.

The methodology and assumptions used to calculate the emissions for the different phases are discussed in the following sections. Different emission factors are used depending on the phase of the project (construction, installation or operations), the type of equipment, vessels and plant used, duration of the activity. A3.2 Onshore fabrication of Offshore Platforms Including Jackets,

Topsides and Drilling Template A3.2.1 Construction and Load-Out A3.2.1.1 Methodology The method used to calculate emissions for the onshore fabrication of the offshore facilities includes assumptions in regards the type of equipment and vehicles used during the construction and load-out programme, the number of vehicles and equipment used, the duration of vehicles and equipment use and emission factor associated with the type of vehicles and equipment used. A worst-case scenario that the equipment is being used continuously for the duration is assumed. The equipment will however, only be used intermittent, so in reality the emissions will be less that what is presented here. All emissions data are presented in tonnes. The following is a worked example to demonstrate application of the methodology used to derive emission estimates: • Six (6) cranes are anticipated to be used for the construction of the DUQ topsides. The

cranes will be used for 10 hours per day and it is assumes that there are 30 days per month. The work will continue for 27 months. The emission factor for cranes is 87,704 kg/h of CO2. Therefore 6 x 10 x 30 x 27 x 87,704 = 4,262 te of CO2 is attributable to the cranes, based on a worst case scenario. There will however, be periods when the cranes are not working and hence the emissions will be intermittent.

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/3 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report A3.2.1.2 Pollutant Emission Factors Tables A3.1 and A3.2 present the pollutant emission factors, their source and what they are used for. These emission factors have been used to estimate emission quantities for topsides and jackets construction activities. Table A3.1 CORINAIR Atmospheric Emission Inventory Guidebook - Emission

Factors for General Plant and Equipment

CO2 CO HCs NOx SOx PM

(g/hr) (g/hr) (g/hr) (g/hr) (g/hr) (g/hr) Tractor 51,161 350 100 580 41 60

Excavator 45,314 310 80 770 65 60

Crane 87,704 600 1,260 3,600 4,390 250

Truck 119,132 815 140 1,890 205 120 Minibus 98,669 450 185 930 101 154 Sideboom 87,704 600 1,260 3,600 4,390 250

Generator 43,852 300 140 1,440 2 110

Table A3.2 US EPA AP-42, Section 3.4, Emission Factors for Diesel Power

Generators lb/MMBtu

NOX 3.20E+00

CO 8.50E-01

CO2 1.65E+02

SO2 2.02E-01

HC 9.00E-02 Methane 8.10E-03 VOC 8.19E-02

PM10 1.00E-01

The conversion factors used are as follows: • lb to tonne: 0.454; and • Btu to Ws: 1,054. A3.2.1.3 Topsides The scope of this section is for the DUQ and PCWU topsides construction. Table A3.3 shows the assumptions used to estimate emissions arising from construction of the topsides, assuming the construction schedule of the DUQ is 27 months and the PCWU, 35 months. The table also shows the number of vehicles that will be required over that period and the rated size of the diesel power generation.

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/4 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report Table A3.3 Assumptions DUQ PCWU Duration 27 35 Months Buses 5 5 Number Cranes 6 6 Number Trucks 10 10 Number Others 10 10 diesel driven equipment Power Generation 1.75 1.75 MW Hours per day 10 10 Hours Days per month 30 30 days A3.2.1.4 Emissions Data Tables A3.4 through A3.6 present the emissions attributable to the power and equipment used for the construction phase of the DUQ and PCWU topsides based on the methodology and assumptions presented above. Emissions are presented in tonnes. Table A3.4 DUQ Topsides Power Generation & Plant/Equipment CO NOX SOX PM CH4 NMVOC CO2 Cranes 29 174 212 12 9 52 4,231 Buses 6 12 1 2 0 2 1,322 Trucks 66 152 16 10 2 10 9,578 Others 25 62 5 5 1 5 3,643 Sub-Total 125 400 235 29 12 69 18,774 Power 111 419 26 13 2 10 21,600 Total 237 819 261 42 14 79 40,374 Table A3.5 PCWU Topsides Power Generation & Plant/Equipment CO NOX SOX PM CH4 NMVOC CO2 Cranes 38 227 277 16 12 67 5,525 Buses 8 16 2 3 0 3 1,727 Trucks 86 198 22 13 2 12 12,509 Others 33 81 7 6 1 7 4,758 Sub-Total 164 522 307 37 16 90 24,519 Power 145 547 35 17 2 13 28,209 Total 309 1069 341 54 18 103 52,727 Table A3.6 Total DUQ & PCWU Topsides Power Generation and Plant/Equipment CO NOX SOX PM CH4 NMVOC CO2 DUQ -Topsides 237 819 261 42 14 79 40,374 PCWU -Topsides 309 1,069 341 54 18 103 52,727 Total 546 1,888 602 96 32 182 93,102

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Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report A3.2.1.5 Jackets The same methodology was applied to calculate the emissions attributable to the construction of the jackets, for both the DUQ and the PCWU. The assumptions are presented in the Table A3.7. Table A3.7 Assumptions DUQ PCWU Duration 25 28 months Buses 5 5 Number Cranes 6 6 Number Trucks 10 10 number Others 10 10 diesel driven equipment Power Generation 1.75 1.75 MW Hours per day 10 10 Hours Days per month 30 30 days A3.2.1.6 Emissions Data The emissions attributable from the plant, equipment and vehicles for the construction of the jackets for the DUQ and the PCWU are presented in Tables A3.8 through A3.10 below. Emissions are in tonnes. Table A3.8 DUQ Jacket Power Generation & Plant/Equipment CO NOX SOX PM CH4 NMVOC CO2 Cranes 27 164 199 11 9 49 3,984 Buses 6 12 1 2 0 2 1,245 Trucks 62 143 16 9 2 9 9,018 Others 23 58 5 5 1 5 3,430

Sub-total 118 377 221 27 11 65 17,677 Power 105 394 25 12 2 9 20,337.00 Total 223 771 246 39 13 74 38,014 Table A3.9 PCWU Jacket Power Generation & Plant/Equipment CO NOX SOX PM CH4 NMVOC CO2 Cranes 30 178 217 12 9 53 4,341 Buses 6 13 1 2 0 2 1,357 Trucks 67 156 17 10 2 10 9,828 Others 26 64 5 5 1 6 3,738

Sub-total 129 410 241 29 12 71 19265 Power 114 430 27 13 2 10 22164 Total 243 840 268 43 14 81 41429 Table A3.10 Total DUQ & PCWU Jackets Power Generation & Plant/Equipment CO NOx SOx PM CH4 NMVOC CO2 DUQ - Jacket 223 771 246 39 13 74 38,014 PCWU - Jacket 243 840 268 43 14 81 41,429 Total 466 1,611 514 82 27 155 79,443

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/6 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report A3.2.2 Installation and Hook-Up & Commissioning (HUC) A3.2.2.1 Methodology The method used to calculate the emissions arising from the installation and HUC of the template, jackets and topsides includes the type of vessels used during the operations, the number of vessels used, the amount of diesel fuel used by each vessel, the duration of the time the vessels are used and the emission factor for the each pollutant species. This gives the tonnes of pollutant per tonne of fuel used. A worst-case scenario in which the vessels are being used continuously and for the duration of the programme is assumed. Vessel usage will however, be intermittent so in reality the emissions will be less that what is presented here. All emissions data are presented in tonnes. A worked example follows: • The Derrick Barge Azerbaijan (DBA) will be used for installation of the DUQ topsides.

The installation programme will be 77 days long. The barge uses 15 te per day of fuel. The emission factor for CO2 is 3.2 tonnes of CO2 per tonne of fuel used. Therefore 1 x 77 x 15 x 3.2 = 6,930 te of CO2 will be attributable to the DBA for the installation and HUC of the DUQ topsides, based on a worst-case scenario. There will however, be periods when the DBA is standing by and may not use the amount of fuel presumed here, hence the emissions will likely be less.

A3.2.2.2 DUQ and PCWU Jackets and Topsides, and Template The scope of this section is for the calculation of emissions for the Template, DUQ and PCWU platform installation and HUC. The tables following shows the emission factors used and the assumptions used for the installation and HUC of the facilities, assuming the duration according to the schedule. It also shows the type of seagoing vessels used in the installation and HUC, the number of vessels used and their fuel usage. A3.2.2.3 Emission Factors for vessels The emission factors used for the calculations are taken from the following source and are relevant for seagoing vessels. Emissions are calculated based on tonne of pollutant per tonne of fuel used. Table A3.11 E&P Forum - Report No. 2.59/197: Tonnes of Emissions per Tonnes of

Fuel Used

Pollutant Tonnes ofpollutant/tonne offuel used

CO2 3.2

CO 0.008

NOX 0.059

SOX 8.00E-03

CH4 0.00027

VOC 0.0024 Table A3.12 Assumptions DUQ PCWU Duration 77 56 days Number of tugs 3 3 80 Tonnes tugs Tug Fuel 6 6 Tonnes/day Number of Barge 1 1 Number (DBA) Barge Fuel 15 15 Tonnes/dy

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Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report A3.2.2.4 Emissions Data The emissions attributable to the installation of the offshore facilities is shown in the following table. All emissions are quoted in tonnes. Table A3.13 Predicted Emissions for the Installation and HUC of the offshore

facilities Pollutant DUQ

(tonnes) PCWU (tonnes)

CO2 8,131 5,914

CO 20 15

NOX 150 109

SOX 20 15

CH4 1 0.5

VOC 6 4 A3.3 Subsea Water Injection development Facilities (Manifolds, WI

Flowlines, Umbilicals) A3.3.1 Installation, Tie-In and Hook-Up & Commissioning A3.3.1.1 Methodology The method used to calculate emissions arising from the installation of the subsea water injection facilities uses the type of seagoing vessels used during the installation programme, the number of vessels used, the fuel usage rate of the vessels, the duration of the programme during which vessels will be used and the emission factors for the pollutants. A worst-case scenario where vessels are being used continuously for the duration is assumed. Vessel use will however, be intermittent, so in reality the emissions will be less than what is presented here. All emissions data are presented in tonnes. The following is a worked example • It is assumed that there will be two (2) supply vessels operating for 47 days. Each has a

fuel usage rate of 6 te/day. The emission factor for CO2 is 3.2 te of CO2 per tonne of fuel used. Therefore 2 x 47 x 6 x 3.2 = 1,805 te of CO2 attributable to the supply vessels for the installation of the subsea facilities, based on a worst-case scenario. There will however, be periods when the vessels will not be in use and hence the emissions will be intermittent.

A3.3.1.2 Emission Factors for vessels Table A3.14 E&P Forum - Report No. 2.59/197 - Tonnes of Emissions per Tonnes of

Fuel Used Pollutant Tonne pollutant/tonne of fuel used CO2 3.2

CO 0.008

NOX 0.059

SOX 8.00E-03

CH4 0.00027

VOC 0.0024

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/8 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report A3.3.1.3 Assumptions Following is the table of assumptions used for the installation, tie in and HUC of the subsea water injection facilities. Table A3.15 Assumptions Vessels No. of

Vessels Fuel used Tonnes/day

Duration (Days)

Pipe-lay-barge 1 15 96

Anchor handling vessel 3 6 96

Pipe-haul barges 4 15 47

Installation barge 1 15 15

Tugs 3 6 15

Supply vessels 2 6 47

Diving support vessel 1 6 80

Survey vessel 1 6 47 A3.3.1.4 Emissions Data The following table is a summary of the predicted emissions attributable to the activities associated with the installation, tie-in and HUC of the subsea water injection facilities. The emissions are quoted in tonnes for the duration of the activity. Table A3.16 Predicted emissions for Subsea development Pollutant Tonnes

CO2 19,142

CO 48

NOX 353

SOX 48

CH4 2

VOC 14 A3.4 Inter-Field Export Pipelines (Oil and Gas) A3.4.1 Installation, tie-in and commissioning A3.4.1.1 Methodology The methodology for calculating the emissions predicted for the installation, tie-in and commissioning of the inter-field pipelines for oil and gas is similar to the previous Section 3. The type and number of seagoing vessels that will be used for this phase, their fuel usage, duration of the operation and the emission factor for the relevant pollutant of interest are assumed. A3.4.1.2 Emission Factors for vessels The emission factors used for calculating the emissions attributable to the installation, tie-in and commissioning of the inter-field pipelines for oil and gas are detailed in Table A3.17. The emissions factors are for sea going vessels and are tonnes of pollutant per tonne of fuel used.

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Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report Table A3.17 E&P Forum - Report No. 2.59/197 - Tonnes of Emissions per Tonnes of

Fuel Used Pollutant Tonne of pollutant/tonne of fuel usedCO2 3.2

CO 0.008

NOX 0.059

SOX 8.00E-03

CH4 0.00027

VOC 0.0024 A3.4.1.3 Assumptions The assumptions used for the installation, tie-in and commissioning of the oil and gas inter-field pipelines are detailed below in Table A3.18. This includes type of seagoing vessel used, how many of them, the duration that they will be required for each operation and the amount of fuel used by each vessel per day. Table A3.18 Assumptions Used for Inter-field Pipelines

Installation & Tie-In No. ofVessels

(Days)

Installation Duration

Tie-In Duration (Days)

Commissioning No. of Vessels

Commissioning Duration (Days)

Fuel usage Tonnes/day

Pipe-lay-barge 1 50 20 - - 15

Anchor handling vessel 3 50 20 - - 6

Pipe-haul barges 4 25 - - - 15

Tugs 3 - - 5 30 6

Supply vessels 2 25 10 - - 6

Diving support vessel 1 25 10 - - 6

Survey vessel 1 25 10 - - 6 A3.4.1.4 Emissions Data The emissions attributable to the installation, tie-in and commissioning of the oil and gas inter-field pipelines are presented in Table A3.19 below. Emissions are in tonnes. Table A3.19 Emissions Associated with Installation of the Inter-field Pipelines Pollutant Tonnes

CO2 12,000

CO 30

NOX 221

SOX 30

CH4 1

VOC 9

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/10 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report A3.5 MODU Pre-Drilling A3.5.1 Methodology It is assumed that pre-drilling activities will be carried out by the Dada Gordud (DDGG). The methodology for calculating the emissions associated with the pre-drilling programme is as follows: 1. Emissions are predicted for getting the DDGG to the site (rig transfer). This involves the

use of seagoing vessels (tugs), the time it takes to get to the site, the amount of fuel used by the tugs and the associated emission factor to calculate the amount of pollutant per tonne of fuel used.

2. The power requirements for the pre-drilling programme are calculated using the fuel used in the diesel power generator on the DDGG, the duration of the pre-drilling programme and the relevant emission factor for engines, giving tonne of pollutant per tonne of fuel used.

3. The helicopters required for transporting personnel to the site. The emissions from this will be the number of trips, the fuel used per trip and the emission factor for helicopter fuel usage.

4. The seagoing vessels required for the pre-drilling programme give rise to emissions that are calculated by the number of seagoing vessels, the duration they are required, the tonnes of fuel used for that duration and the relevant emission factor for tonne of pollutant per tonne of fuel used.

5. Flaring due to the oil and gas flared during the well testing will result in emissions from oil and gas being flared. The emissions resulting from this are calculated by number of well test conducted, the duration of the well test, the amount of oil and gas predicted to be flared, and the relevant emission factors for oil and gas, based on tonne of pollutant per tonne of gas and oil flared.

A3.5.1.1 Emission Factors The emission factors used in the calculations for the pre-drilling phase are taken from the following source and are tonnes of pollutant per tonne of fuel burnt. Table A3.20 Emission Factors (E&P Forum - Report No. 2.59/197) - Tonnes of

Emissions per Tonnes of Fuel Used

Pollutant Engines Helicopters Vessels Flare Gas Flare Oil CO2 2.75 3.2 3.2 2.61 3.08 CO 0.019 0.0052 0.008 0.0087 0.0014 NOx 0.07 0.0125 0.059 0.0015 0.0078 SOx 8.00E-03 8.00E-03 8.00E-03 0.0000128 0.004 CH4 0.00014 0.000087 0.00027 0.035 0.002 NMVOC 0.0019 0.0008 0.0024 0.015 0.048

A3.5.1.2 Assumptions The assumptions used in the calculations of the seagoing vessels and DDGG are presented in Table A3.21.

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Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report Table A3.21 Assumptions Used for Vessels

Rig transfer: 4 days Pre-drilling programme duration: 685 days Dada daily diesel fuel consumption: 9 Tonnes Standby vessel: 3 Tonnes Supply Vessel: 6 Tonnes Vessel trips: 7 trips per week Helicopter 0.24 Tonnes/hr Helicopter trips: 4 Return trips per week Helicopter trip duration: 1.5 Hours

Table A3.22 Assumptions Used for Flaring During Well Tests

Number of well tests: 2 wells Testing period: 32 hours per well Oil flared: 4,000 bbl per well Oil flared: 1,018 Tonnes for testing period Gas Oil Ratio (GOR): 1250 scf/bbl (worst-case) Gas flared: 18750000 scf per well Natural gas: 0.04 lb/SCF Gas flared: 358 Tonnes of gas per well

A3.5.1.3 Emissions Data Table A3.23 Emissions Associated with Pre-drilling Programme Rig Transfer Power Gen Helicopters Vessels Flaring TOTAL

CO2 230 16,954 451 19,728 13,620 50,983

CO 1 117 1 49 12 179

NOX 4 432 2 364 31 832

SOX 1 49 1 49 15 116

CH4 0 1 0 2 33 35

NMVOC 0 0 0 15 194 209 A3.6 Offshore Facility Offshore Operation Including Start-Up The following section presents the pollutant emission factors, general assumptions and emissions data for the various atmospheric emissions contributors at the offshore platform facilities for the operational years 2008 to 2024. The main sources of emissions considered are those from fuel gas consumption (generators for power generation and water injection) and any potential flaring, including the flare purge and pilot as a continuous source. The estimates include flaring as a result of start up, which is based on 75%, 85% and 95% availability of processing plant and equipment for years 1, 2 and 3+, respectively. From year 2011 onwards, it has been assumed that 1% of gas produced per year will be flared. It is also assumed that 86% of this volume will be flared offshore at the platforms with the balance of 14% will be flared onshore at the terminal (see Technical Appendix 4 on onshore operations). SO2 emissions resulting from potential H2S in the gas are not expected for DWG. A3.6.1 Methodology The methodology used to calculate emissions attributable to the operation of the offshore facility is based on the production profile for oil, gas and water, over the life of the PSA, 2008 – 2024. From this, the power required for production and processing at the offshore facilities

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/12 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report is calculated taking into account number of generators required. The fuel needed to produce the power required is calculated, taking into account the need to operate the equipment at lower loads. The total fuel gas usage is multiplied by the appropriate emission factor to give the tonnes of pollutant per tonne of fuel gas used. Emission Factors are different for combustion than for flaring due to the different combustion qualities of the processes. Fuel usage in SCF is converted to tonnes with the following conversion factors to derive tonnes pollutant per tonne of fuel burnt: • 0.04 lb/SCF; and • 0.000454 lb of gas/tonne. A3.6.1.1 Emission Factors The emission factors used for calculating the atmospheric emissions attributable to the combustion and flaring during operations are shown in the Table A3.24 and are taken from the source noted. Table A3.24 Emissions Factors (E&P forum July 1995) tonnes of pollutant per tonne

of fuel burnt. CO2 CO NOX CH4 VOC Fuel gascombustion

2.8100 0.0027 0.0067 0.0004 0.00051

Gas Flaring 2.8 0.0087 0.0015 0.01 0.01 The main source of emissions and whether they will be continuous or intermittent, are listed in Table A3.25. Table A3.25 Main Sources of Emissions from Operations

Process Equipment Continuous or Intermittent operation

Water Injection: 3 x RB211 generators Continuous operation for WI, but not all 3 running continuously over the life of the PSA

Power Generation: 5 x RB211 n+1 configuration, continuous operation but not all running continuously over the life of the PSA

Flaring: 1% of gas produced with 86% flared offshore. Intermittent

Flare Purge: 600 MMscf/year Continuous

Flare Pilot - HP and LP: 4 MMscf/year Continuous

A3.6.2 Emissions Data A3.6.2.1 Combustion Emissions The offshore emissions during operations have been separated into combustion emissions and flaring emissions. The combustion emissions are due to normal operations of the offshore facilities. The emissions are presented in Tables A3.26. Emissions are in tonnes.

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Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report Table A3.26 Offshore Combustion Emissions (Power Generation & Water Injection) Year CO2 CO NOx CH4 VOC 2008 378630 364 903 57 7 2009 584365 561 1393 87 11 2010 684611 658 1632 102 12 2011 695799 669 1659 104 13 2012 755495 726 1801 113 14 2013 754561 725 1799 113 14 2014 756939 727 1805 113 14 2015 704443 677 1680 105 13 2016 693760 667 1654 104 13 2017 685122 658 1634 102 12 2018 654408 629 1560 98 12 2019 641181 616 1529 96 12 2020 436026 419 1040 65 8 2021 430035 413 1025 64 8 2022 430350 414 1026 64 8 2023 430039 413 1025 64 8 2024 432821 416 1032 65 8 Totals 10148585 9751 24198 1517 184 A3.6.2.2 Flaring emissions offshore Flaring will be an intermittent source of emissions, except for purge and pilot, which is relatively small. The assumptions are that 1% of the gas produced is flared and of that 86% will be preferentially flared offshore. The emissions are presented in Tables A3.27. Emissions are in tonnes. Table A3.27 Offshore Flaring Emissions (Flaring / Flare Purge & Pilot) Year CO2 NOX CO CH4 VOC 2008 367600 40 235 270 270 2009 334723 65 378 434 434 2010 260406 68 393 452 452 2011 73712 40 231 265 265 2012 72779 39 228 262 262 2013 73374 40 230 264 264 2014 73291 40 229 264 264 2015 61150 33 191 220 220 2016 47260 26 148 170 170 2017 41583 22 130 150 150 2018 28777 16 90 104 104 2019 22142 12 69 80 80 2020 18489 10 58 67 67 2021 16160 9 51 58 58 2022 18758 10 59 67 67 2023 17612 10 55 63 63 2024 20122 11 63 72 72 Totals 1547940 489 2837 3261 3261

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/14 October 2004

Azeri, Chirag & Gunashli Full Field Development Phase 3 Environmental & Socio-economic Impact Assessment Final Report A3.6.2.3 Total emissions due to Offshore Operations Table A3.28 presents the combined combustion and flaring emissions by species for the offshore operations. Emissions are in tonnes. Table A3.28 Total Offshore Emissions CO2 CO NOX CH4 VOC Combustion 10148585 9751 24198 1517 184 Flaring 1547940 489 2837 3261 3261 11,696,525 12,588 24,687 4,778 3,445

31648-046 ACG Phase 3 ESIA Technical Appendix 3 A3/15 October 2004