2025-02-19T09:02:45+00:00 2025-02-19T09:02:45+00:00 macOS Version 15.0.1 (Build 24A348) Quartz PDFContext tetml={filename={D:\drim\repository\projects\drim_123_0\metadata\a\f\afe9f1977013f37b056fede80a693652\afe9f1977013f37b056fede80a693652.tet.xml} elements={annotations=false bookmarks=false destinations=false fields=false javascripts = false} } granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} PROJECT Company Document ID 11111111100011001 Basis of Design for Project This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Sheet of Sheets 1 / 44 Validity Status Revision Number AB-DE 03 AB-DE 03 21-09-24 Issued for Information Project Team M.Schmid M.Schmid AB-DE 02 20-11-20 Issued for Information Project Team M.Schmid M.Schmid AB-DE 01 30-09-20 Issued for Information Project Team M.Schmid M.Schmid AB-DE 00 17-09-20 Issued for Information Project Team M.Schmid M.Schmid Validity Revision Status Number Date Description Prepared Checked Approved Revision Index Company logo and business name Company Document ID 11111111100011001 Contractor logo and business name Project name PROJECT Document Title Basis of Design for Project Facility and Sub Facility Name Scale Document ID Contractor Document ID 11111111100011001 n.a. Supersedes N. Superseded by N. Plant Area n.a. Sheet of Sheets 1 / 55 Plant Unit n.a. Software: Microsoft Word File Name: 11111111100011001_CDFDF_54.doc granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 00 Issued for Information 01 Issued for Information – Flexible Jumper selected on 2/4 02 Issued for Information – Update of Design Data Design – Section 10.1 03 Issued for Information – Update of configuration granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} INDEX 1 EXECUTIVE SUMMARY ..................................................................................................................................... 5 2 INTRODUCTION .................................................................................................................................................. 6 2.1 DEVELOPMENT .......................................................................................................................................................................................... 6 2.2 DEVELOPMENT STRATEGY ........................................................................................................................................................................... 6 3 LOCAL ACTS, LAWS, RULES AND REGULATIONS ............................................................................. 7 3.1 ENVIRONMENTAL EMISSION LIMITS ............................................................................................................................................................... 7 3.2 REGULATORY COMPLIANCE ......................................................................................................................................................................... 7 3.3 ORDER OF PRECEDENCE ................................................................................................................................................................................. 7 4 ABBREVIATIONS, REFERENCES, CODES & STANDARDS ............................................................. 8 4.1 ABBREVIATIONS AND ACRONYMS ................................................................................................................................................................... 8 4.3 DEFINITIONS ............................................................................................................................................................................................. 10 4.4 REFERENCE DOCUMENTS ........................................................................................................................................................................... 10 4.5 CODES & STANDARDS ................................................................................................................................................................................... 11 4.6 UNITS OF MEASUREMENTS ........................................................................................................................................................................... 12 4.7 COORDINATE GRID REFERENCE SYSTEM ...................................................................................................................................................... 13 5 PROJECT DESCRIPTION ............................................................................................................................... 14 5.1 DEVELOPMENT SCENARIO ......................................................................................................................................................................... 14 6 GENERAL LOCATION DATA ......................................................................................................................... 15 6.1 CLIMATOLOGY AND METOCEAN DATA ................................................................................................................ 15 6.1.1 Water Depths ............................................................................................................................................ 15 6.1.2 Offshore Plant Location ............................................................................................................................... 15 6.1.3 Onshore Plant Location ............................................................................................................................... 15 6.1.4 Enviromental Data ..................................................................................................................................... 15 6.2 GEOPHYSICAL AND GEOTECHNICAL DATA ........................................................................................................... 16 6.2.1 Geotechnical ............................................................................................................................................. 16 6.2.2 Geophysical .............................................................................................................................................. 16 6.2.3 Bathymetry Data ........................................................................................................................................ 16 6.2.4 Geohazard Assessment ............................................................................................................................ 17 6.2.5 Earthquake Data ........................................................................................................................................ 17 7 RESERVOIR MANAGEMENT BASIS .......................................................................................................... 18 7.1 MAIN RESERVOIR DATA ................................................................................................................................................................................ 18 7.2 RESERVOIR FLUID COMPOSITION .................................................................................................................................................................... 20 7.3 PRODUCTION CAPACITY OVERVIEW AND PROFILES ................................................................................................................................... 21 8 DRILLING & COMPLETIONS ....................................................................................................................... 29 8.1 DRILLING AND COMPLETIONS OVERVIEW ..................................................................................................................................................... 29 8.2 WELLS TARGETS COORDINATES ...................................................................................................................................................................... 29 8.3 PRELIMINARY CASING DESIGN ..................................................................................................................................................................... 30 8.4 COMPLETION SCHEMATICS ....................................................................................................................................................................... 33 8.5 PRELIMINARY METALLURGY AND ELASTOMERS SELECTION ....................................................................................................................... 35 9 FLUID DATA AND PRODUCTION CHEMISTRY .................................................................................. 36 9.1 RESERVOIR FLUID PROPERTIES ...................................................................................................................................................................... 36 granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 9.2 RESERVOIR FLUID COMPOSITION .................................................................................................................................................................... 36 9.3 SCALE POTENTIAL ......................................................................................................................................................................................... 36 9.4 WAX FORMATION AND RHEOLOGY ............................................................................................................................................................ 36 9.5 HYDRATE EQUILIBRIUM CURVES .................................................................................................................................................................. 36 9.6 HYDROGEN SULPHIDE ................................................................................................................................................................................. 37 9.7 ASPHALTENES ............................................................................................................................................................................................. 37 9.8 MATERIAL SELECTION ............................................................................................................................................................................... 37 9.8.1 CO2 Corrosion ............................................................................................................................................ 37 9.9 FLOW ASSURANCE ISSUES ............................................................................................................................................................................ 38 9.10 FLOWING AND SHUT IN CONDITION ........................................................................................................................................................... 38 9.10.1 Flowing Well Head Pressure ....................................................................................................................... 38 9.10.2 Flowing Well Head Temperature ................................................................................................................ 39 9.10.3 Topside Arrival Pressure/Temperature ........................................................................................................ 39 9.10.3.1 Operating Cases ............................................................................................................................................... 39 9.10.3.2 Inlet Flowrate FPU JKK ........................................................................................................................................ 40 9.10.3.3 Target LP Max Flowrate ....................................................................................................................................... 41 9.11 PRODUCT SPECIFICATION ......................................................................................................................................................................... 42 9.11.1 Produced Oil Specification ............................................................................................................................ 42 9.11.2 Produced Treated Water ............................................................................................................................. 42 9.11.3 H2S Content ................................................................................................................................................ 42 9.11.4 CO2 Content ............................................................................................................................................... 43 9.12 FIELD FLOWRATES FOR DESIGN PURPOSE ................................................................................................................................................ 43 10 FACILITIES ...................................................................................................................................................... 44 10.1 SUBSEA, UMBILICAL AND FLOWLINES .......................................................................................................................................................... 44 10.1.1 FPU ............................................................................................................................................................ 44 10.1.2 Design Life .................................................................................................................................................. 44 10.1.3 Maximum Water Depth ............................................................................................................................. 44 10.1.4 Main Subsea Equipment ............................................................................................................................. 44 10.1.5 Umbilicals .................................................................................................................................................. 45 10.1.6 Control System Description .......................................................................................................................... 46 10.1.7 Flowlines System ....................................................................................................................................... 46 11 HEALTH, SAFETY, ENVIRONMENT ...................................................................................................... 48 11.1 SAFETY CRITERIA ......................................................................................................................................................................................... 48 11.2 HEALTH CONSIDERATIONS ....................................................................................................................................................................... 49 AS PER ABOVE, THE HEALTH RELATED RISK BASED APPROACH WILL INCLUDE THE FOLLOWING OBJECTIVES ........................................................... 49 11.3 SIMOPS ............................................................................................................................................................. 49 11.4 RISK IDENTIFICATION ....................................................................................................................................... 49 11.5 ENVIRONMENTAL, SOCIAL AND HEALTH IMPACT ASSESSMENT ................................................................................................................. 51 12 GHG EMISSION AND MITIGATION OF CLIMATE CHANGE EFFECTS ................................ 52 12.1 WATER MANAGEMENT .............................................................................................................................................................................. 52 13 REGULARITY AND OPERATION ............................................................................................................ 53 14 SIMOPS AND CONOPS REQUIREMENTS .......................................................................................... 54 15 ATTACHMENTS ............................................................................................................................................... 55 granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 1 EXECUTIVE SUMMARY This document defines the preliminary Basis of Design for the SURF and the Flexible Line relevant to Development Project. The document comprises reservoir characteristics, fluid properties and well production data. It also contains the available geomorphological and meteocean design data. The document also provides a description of the preliminary system configuration, which will be further developed by the Tenderers. This document will be enriched and updated as necessary along the project roadmap and possibly at the beginning of each new Project phase. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 2 INTRODUCTION 2.1 Development The discovery is located in the REGION (Op. 40%, Pertamina 30%, Neptune 30%) operated by Ltd., within the Kutai basin, offshore East Kalimantan area in Borneo island - Indonesia. REGION was awarded in 22 nd August 2019 with gross- split REGION terms, however the effective date is 26 th January 2020. Figure 1: Location Map -1 well, operated by Gas Brand, was spud on 21 st May 2002 in water depth of -2,436 ft. The well reached a TD of 13,441 ftMD (-13,100 ftTVDSS) on 7 th June 2002. The discovery was already successfully explored by the Gendalo-4 operated by Unocal in 2001. Both wells lie to the SW of Gendalo structure from which discovery is separated by a saddle. 2.2 Development Strategy The development concept of is subsea tie-in to the current existing Jangkrik facilities considering the available ullage at the late life of Jangkrik and the location in vicinity of Jangkrik Main Clusters. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 3 LOCAL ACTS, LAWS, RULES AND REGULATIONS 3.1 Environmental Emission Limits Refer to [7]. Should some special operations related to field (e.g. pre-commissioning activities of flowline) imply a possible impact to the environment, these will have to be properly assessed with the HSE function to verify any constraints to be satisfied. 3.2 Regulatory Compliance Refer to [3]Errore. L'origine riferimento non è stata trovata.. 3.3 Order of Precedence The local acts, laws, rules and regulations applicable to this project shall be the same of those relevant to Jangkrik field. The most stringent rules shall be applied. In the event of scope overlapping of different rules, the most stringent requirement shall apply. The following shall be the order of precedence, 1 being the highest precedence level (see ref. [3] for complete list of applicable standards): 1. Indonesian Laws, Regulations and International Conventions signed and/or endorsed by Indonesia, applicable to offshore installations. 2. Classification Rules (as applicable to the concerned type of equipment), Flag Regulations, Marine International Rules and Certification Society. 3. Project Documentation (Appendix D) 4. Company Standards (for new equipment, last revision of Company Standards shall be used – as per ref. [3]Errore. L'origine riferimento non è stata trovata.). 5. International codes and standards. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 4 ABBREVIATIONS, REFERENCES, CODES & STANDARDS 4.1 Abbreviations and Acronyms The followings will be applied to this document: API Degree(s) API BOPD Barrels of Oil Per Day BLPD Barrels of Liquid Per Day BWPD Barrels of Water Per Day CDT Cool Down Time CPT Cone Penetration Test CGR Condensate Gas Ratio CITV Chemical Injection Throttling Valve CJB Cable Jointing Box E&I Electrical and Instrumentation EJB Electrical Junction Box EPU Electric Power Unit FPU Floating Production Unit FTHP Flowing Tubing Head Pressure HC Hydrocarbon HIPPS High Integrity Pressure Protection System HP High Pressure HPU Hydraulic Power Unit ID Internal Diameter ILT In Line Tee ITT Invitation To Tender JKK Jangkrik Main JNE Jangkrik North East LCP Local Control Panel LER Local Equipment Room LNG Liquefied Natural Gas LP Low Pressure MEG MonoEthylen Glycol MeOH Methanol MMBLPD Million Barrel of liquid per day MMSCFD Million of Standard Cubic Feets per Day MSL Mean Sea Level MWA Mid Water Arch ND Nominal Diameter OD Outer Diameter OJB Optical Junction Box ORF Onshore Receiving Facilities P&ID Piping and Instrumentation This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} PLET Pipe Line End Termination PLR Pig Laucher Receiver ppmv Parts per Million, Volumetric PVT Pressure, Volume, Temperature PW Produced Water RAM Reliability Availability Maintainability ROV Remotely Operated Vehicle RVP Reid Vapor Pressure SCM Subsea Control Module SDU Subsea Distribution Unit SDV Shut Down Valve SoW Scope of Work SI International System of Units SITHP Shut-In Tubing Head Pressure SMLS Seamless SPS Subsea Production System SURF Subsea, Umbilical, Riser and Flowline SSIV Subsea Safety Isolation Valve TBD To be Defined TUTU Topside Umbilical Termination Unit TVDSS True Vertical Depth SubSea TVP True Vapor Pressure UPS Uninterruptible Power Supply UTA Umbilical Termination Unit XT Christmas Tree WD Water Depth WHFP Well Head Flowing Pressure WHSIP Well Head Shut-In Pressure WHFT Well Head Flowing Temperature This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 4.3 Definitions The following definitions apply to this document: FLOWLINE PIPELINE SEALINE STABILISED CONDENSATES 4.4 Reference Documents Generic term adopted for hydrocarbon transportation lines that connect onshore/offshore installations (synonym of pipeline) Generic term adopted for hydrocarbon transportation lines that connect onshore/offshore installations (synonym of flowline) Term referred to hydrocarbon transportation lines that connect offshore installations to shore Treated HC Fluid that can be stored at ambient temperature and pressure in liquid phase without significant boil-off generation. [Ref n°] Document Name Document Number Notes [1] Field General Layout and Details 220814BGDP00039 [2] Subsea Block Diagram 220814BGRB00036 [3] International Codes and Company Standards 220814BGES00006 [4] Deleted Deleted [5] Field Development - Basis of Design [6] Health, Safety and Environmental (HSE) Philosophy [7] Indonesian Environmental Emission Limits [8] Development – Process Report 220814FGRB00011 000589_DV_CS.HSE.0048.000_01 000589_DV_CS.HSE.0118.000_00 220814FPRA00013 [9] Facilities Report 220814FGRV00012 [10] e-EHXT P&ID 220814BUFM00053 [11] Control System Block Diagram 220814BGFB00037 [12] UTA P&ID 220814BUFM00052 [13] HIPPS P&ID 220814BUFM00047 [14] Subsea Structure P&ID 220814BUFM00045 [15] TEE Structure P&ID 220814BUFM00046 [16] Corrosion Control and Material Selection report 220814BXRV00026 [17] Flow Assurance Report 220814BBRV00014 [18] PROJECT field development drilling & COMPLETION PRE- FEASIBILITY STUDY COAP/SU–P-1-P-28155 This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Feasibility document Feasibility document Feasibility document Feasibility document Feasibility document Pre- feasibility study granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} [19] Pre-FEED Work for IDD Concept GLO-D200-UFA-BOD-WPI-000- Evaluation 10001 [20] Flow Assurance Design Basis GLO-D200-UFA-BOD-WPI-000- 10001 [21] Flow Assurance Report 220814FPRV00014 [22] Topside Process Description 220801DPRV10009 [23] Phase 2 – Process Verification Report – Dual Mode Case 750 Inlet [24] Jangkrik Phase 2 – FEED Process Report 220801BPR00329 220801BGRV00151 [25] SPS Basis of Design RP_A11111v1 – Main (Feb 2012) [26] EPCI 2 – Basis of Design 220802BGRB45230 [27] Basis of Design and Functional Requirements for FPU detail design 220801DGSH45183 [28] Basis of Design for Merakes Project 220800BGRBM1366 [29] Subsea System and Subsea Control System Description and philosophy [30] SCS (Subsea Control System) Data Sheet 220814BURB00041 220814BUGA00056 [31] Umbilical System Data Sheet 220814BUGA00057 [32] SURF Design pressure definition and verification 220814BUCA00040 This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Feasibility document The original engineering design documentation relevant to existing facilities are to be taken into account for the design. 4.5 Codes & Standards As a minimum all activities shall comply with Indonesia Regulation and International & Company Standards as detailed in document ref. [3]. 4.6 Units of Measurements The following reference conditions shall be applied when needed: Reference Temperature [°C] Pressure [bara] Standard Conditions 15.56 1.013 Normal Conditions 0 1.013 Table 1: Reference Conditions granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} The units of measurement will be generally expressed according to S.I. except for the following differences: Unit Symbol Notes Temperature °C barg Gauge pressure Pressure bara Absolute pressure Time h Reid Vapor Pressure psi (RVP) True Vapor Pressure psia (TVP) Mass Flow kg/h Molar Flow kmol/h kWe Electric Power Low duty Energy Flow Gas Flow Liquid Flow MWe Electric Power High duty 10 6 W MWth Thermal Power MMSCFD 10 6 SCFD MMSCMD 10 6 SCMD Barrels per day at standard BLPD conditions 1 BLPD = 0.1589873 m 3 /day MMBLPD 10 6 BLPD Gas quantities BSCF 10 9 SCF Barrels at standard conditions Liquid quantities MMBBL 10 6 BBL 1 MMBBLS = 158,987.3 m 3 ppmv Parts per Million, Volumetric Contaminant content mg/Nm 3 10 -3 grams per normal cubic meter Gas Oil Ratio (GOR) SCF/BBL At standard conditions Reservoir permeability mD milli-Darcy Fouling Factor m 2 –h °C /kcal Steel and concrete N/mm strength 2 Diameter of pipe Inches Gas Flowrate MMSCFD Table 2: Units of Measurement This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 4.7 Coordinate Grid Reference System All reported coordinates for the project were referenced to the World Geodetic System WGS84 datum based on the WGS84 spheroid, and are projected in Universal Transverse Mercator coordinates for Zone 50 in the southern hemisphere (UTM 50 S). Units are in meters. Project will use the same system of Jangkrik Project. Spheroid Spheroid name WGS84 Semi-major axis (a) 6 378 137.000 Semi-minor axis (b) 6 356 752.314 Inverse flattng (1/f) 298.257 223 563 Eccentricity squared (e^2) 0.006 694 380 07 5 PROJECT DESCRIPTION 5.1 Development Scenario Projection Parameters – EPSG 32750 Projection name Universal Transverse Mercator (UTM) Projection type Transverse Mercator Zone 50 South Central Meridian (CM) 117° East Origin latitude 0° North False Easting 500,000 m False Northing 10,000,000 m Scale factor at CM 0.9996 Units Meters Table 3: Coordinate system The Gas discovery well, -1, was drilled by Gas Brand in 2,436’ water depth ( Indonesia partner at 20%) and reached TD on June 7th 2002 at -13,100’ TVDSS. After un-successful proposals on the Development of and other Gas discoveries in the Area, Gas Brand released the acreage. Indonesia earned the ownership of the exploration and exploitation rights on acreage again after successful bidding at the Indonesia’s 2019 bidding round. development represents an excellent synergy opportunity to extend the life of the Jangkrik Asset: the declining production profile in Jangkrik will enable to provide additional value and reserves to . The project is going to provide further value to the Government of Indonesia and to the stakeholders along the gas processing and commercialization chain, from the Field to the Terminals, the Bontang LNG plant. The development concept of is subsea tie-in to the current existing Jangkrik facilities considering the available ullage at the late life of Jangkrik and the location in vicinity of This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Jangkrik Main Clusters. The n.2 new wells are tied-back to Jangkrik Trunkline 1 by means of one new subsea production flowline, while the production of Jangkrik Cluster 1 is sent to Jangkrik Cluster 3 6 GENERAL LOCATION DATA 6.1 CLIMATOLOGY AND METOCEAN DATA Figure 2 – Development Scenario For the environmental data as seawater temperature, currents and waves, ref. to [25]. 6.1.1 Water Depths The water depths in the area ranges from 300 m to 1200 m below mean sea level. 6.1.2 Offshore Plant Location Jangkrik FPU coordinates Item X [m] Y [m] Latitude Longitude FPU centre 572421 9860512 1° 15’ 42,868” S 117° 39’ 03,499 E Table 4: Jangkrik FPU Coordinates This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 6.1.3 Onshore Plant Location Jangkrik Existing ORF coordinates The coordinates of the existing ORF for Jangkrik are as here described: • Latitude: 9899144 N to 9899370 N • Longitude: 519077 E to 519329 E 6.1.4 Enviromental Data For the environmental data as seawater temperature, currents and waves, refer to following document (Ref.[25]): Doc n° Doc. title Revision RP_A11111v1 – Main (Feb 2012) SPS Basis of Design Table 5: Metocean Data Return periods for which oil and gas structures might be designed are set by national regulation or guidelines. For the typical return periods refer to Company Standard 28842.ENG.OFF.STD “Meteo-Oceanographic Design Basis”. 6.2 GEOPHYSICAL AND GEOTECHNICAL DATA 6.2.1 Geotechnical No geotechnical data are available for development area. A dedicated geotechnical survey will be performed in the next project phases, with the aim to define the soil characterization at the locations identified for the installation of the subsea structures, flowlines and umbilicals. 6.2.2 Geophysical No geophysical data are available to date for development area. A dedicated geophysical survey will be performed in the next project phases, with the aim of gathering detailed information concerning the geomorphological characteristics of the seabed and the shallow subsurface. The survey results will provide detailed bathymetry, seabed features identification, shallow stratigraphy and related potential hazards. 6.2.3 Bathymetry Data No detailed bathymetric/morphological data are available for the project area. Some preliminary information has been derived with a reprocessing of a 3D seismic volume, that provided a low resolution (12.5m x 12.5m) bathy-morphological map (Figure 3 and Figure 4). The area is characterized by several canyons (main and tributary), visible faults, steep slopes, indented profiles and also isolated mounds. Water depth in the development area ranges from 300 m to 1500 m. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Figure 3 – General Morphology of the area derived from a 3D seismic volume. Black Circle defines the development area. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Figure 4 – General Morphology of the area derived from a 3D seismic volume. Detail of the area of interest 6.2.4 Geohazard Assessment No geohazard studies have been performed with focus on development area. 6.2.5 Earthquake Data ISO 19901-2 shall be considered for the design of subsea structures and foundations 7 RESERVOIR MANAGEMENT BASIS 7.1 Main Reservoir Data The primary reservoir discovered in Field is T-090 (equivalent to 3130 based on previous Gas Brand nomenclature) and it was penetrated at a depth of approximately -2,400 to -2,600 meter subsea true vertical depth (TVDSS). Secondary reservoirs are T-088-T-086 (equivalent to 3140 and 3150 based on previous Gas Brand nomenclature ) and T-084 Segment-1 (equivalent to 3170 based on previous Gas Brand nomenclature). field is a Pliocene turbidite deposited 3.5 million years ago as toe-of-slope fans that draped over an anticlinal structure that is part of the greater Gendalo Hub anticline. The trap at the field is stratigraphic, formed by the pinch-out of Pliocene turbidites up-dip into a slope valley. The T-090 reservoir is the primary gas accumulation and contains approximately 74% of the total gas-in-place. The amplitude, ESP, and SpecD maps clearly show the toe-of-slope fan geometry and the opng neck of the slope valley feeding the fan from the northwest. Based on the revised depositional model is characterized by a channel-attached fan system with presence of potential barriers. The T-090 package thins up-dip into the slope valley and, while the entire package correlates well seismically, the internal stratigraphic complexities are not well defined. The depositional lobes show a compensational stacking; these events often can amalgamate laterally making difficult to define the reservoir architecture. No GWC was recognized at well locations; RMS amplitude shut off suggests a contact near to -2560 mssl. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} The T-088/T-086 reservoirs was encountered 30-40 meters below the primary reservoir. The reservoir consists of two distinct sand bodies in the -1 and Gendalo-4 wells that share the same gas and water gradient based on MDT pressure data. The up-dip -1 well found a GWC @ -2,556 meter while the down-dip Gendalo-4 was found wet. GWC at -1 well position was confirmed by the -1 and Gendalo-4 pressure gradient analysis. T088- T086 seems to be a more channelized systems with two main fairways oriented NW-S and NW-SE. In the SE area probably, there are some features that could be related to bottom currents reworking or crevasse splays. The T-084 is the basal sand in the Pliocene slope valley depositional system. RMS amplitude extraction suggests a possible channels systems in -1 area and a stratigraphic expansion with depositional lobes in the area south of Gendalo-4. T-084 was found gas bearing in -1 well, while Gendalo-4 didn’t reach this target. -1 well encountered a GWC at -2,626 m TVDSS which is confirmed by MDT pressure points. -1 MDT pressure analysis shows that the T-084 is over-pressured relative to the shallower reservoirs. Based on the petrophysichal evaluation of the explorative wells done in 2020, as part of the Integrated Reservoir Study, -1 and Gendalo-4 penetrated the T90, T088-T086 and T084 encountering the thickness and founding petrophysichal properties as indicated in table below. Wells Reservoir Gross Interva l m TVD Net Reservoi r m TVD NTG Reservoi r Avg. PHIE Reservoi r This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Avg. Swe Pay Avg. Perm. Reservoir -1 23 21 0.9 0.25 0.42 76 mD T90 Gendalo-4 54 43 0.8 0.26 0.45 129 mD -1 72 34 0.46 0.24 0.48 109 mD T88/86 Gendalo-4 55 24 0.43 0.25 - 177 mD -1 21 20 0.94 0.30 0.16 288 mD T84 Gendalo-4 Not Penetrated Table 6 – Summary of the average properties of reservoirs, based on the explorative wells. A 3D model was built to capture all the correctly scaled reservoir characteristics that have been identified from seismic, well, and analog data, and delivers an original gas-in-place. The volumetric field average properties are reported in the table below. Avg NTG Avg Porosity Avg SW Case [%] [%] [%] Reference Case 67% 27% 39% T090 75% 27% 41% T088-086 43% 25% 44% T084 83% 33% 20% granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Table 7 – Average reservoir properties from volumetrics PVT experiments are not available in field. In order to characterize the reservoir fluid, gas composition and CGR from MDT sampling have been considered. The reference sample, taken in T090 level at a depth of 8158 ft (2486.6 m), pressure of 3903 Psia and a temperature of 151 °F, has a C1 content of 98.3%, a gas gravity of 0.58 and a CGR of 5.8 Stb/MMscf. The data have matched by means of an equation of state in PVTi software. The T90 PVT has been considered for the other levels of the field. Properties Value Reservoir Pressure (bara) 270-272 Reservoir Temperature (°C) 73-74 Table 8 – Reservoir Fluid Conditions and Properties -2 well was recently drilled (May 2021) and preliminary petrophysichal analysis confirms the good reservoir quality of the primary target (T-090), on which the development of the field is based. PVT and core analysis results are not yet available at the time of the present BoD. 7.2 Reservoir Fluid Composition The reservoir pressure, temperature and fluid properties for reservoir are reported at para.7.1, while its compositions is tabulated as follows . Component %mol MW Specific Gravity Critical Temp. °C Critical Pressure bara Acentric factor This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. boiling Temp. °C Critical vol. cm3/mol N2 0.040 28.01 -147.0 33.9 0.0400 -195.8 89.8 CO2 0.919 44.01 31.1 73.8 0.2250 -78.5 94.0 C1 98.200 16.04 -82.6 46.0 0.0080 -161.6 99.0 C2 0.200 30.07 32.3 48.8 0.0980 -88.6 148.0 C3 0.090 44.10 96.7 42.5 0.1520 -42.5 203.0 i C4 0.020 58.12 135.0 36.5 0.1760 -11.8 263.0 nC4 0.020 58.12 152.1 38.0 0.1930 0.5 255.0 i C5 0.010 72.15 187.3 33.8 0.2270 27.9 306.0 nC5 0.010 72.15 196.5 33.7 0.2510 36.1 304.0 C6 0.011 86.18 0.664 234.3 29.7 0.2960 68.8 370.0 C7 0.097 96.00 0.702 260.7 28.7 0.3371 92.0 521.9 C8 0.079 107.00 0.730 282.3 26.8 0.3740 116.8 532.0 C9 0.065 121.00 0.754 306.9 24.6 0.4202 142.3 561.5 C10 0.052 134.00 0.776 328.2 23.5 0.4627 165.9 592.4 C11 0.041 147.00 0.795 348.0 21.8 0.5007 187.3 628.0 C12 0.031 161.00 0.813 368.1 20.6 0.5428 208.4 672.2 C13 0.023 175.00 0.829 387.1 19.7 0.5837 227.3 719.9 Table 9 – Reservoir Fluid Composition granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 7.3 Production Capacity Overview and Profiles Two reference Production profiles are reported below: - Constrained case (max trunkline flowrate 230 MMSCFD) Well Gas Rate (MMSCFD) Well Cond Rate (STBD) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Well Water Rate (STBD) Year Month -3 -4 -3 -4 -3 -4 2026 2027 2028 Jan 0 0 0,0 0,0 0,0 0,0 Feb 0 0 0,0 0,0 0,0 0,0 Mar 0 0 0,0 0,0 0,0 0,0 Apr 0 0 0,0 0,0 0,0 0,0 May 0 0 0,0 0,0 0,0 0,0 Jun 0 0 0,0 0,0 0,0 0,0 Jul 0 0 0,0 0,0 0,0 0,0 Aug 4 4 0,0 0,0 0,0 0,0 Sep 100 100 0,0 0,0 0,0 0,0 Oct 107 107 0,0 0,0 0,0 0,1 Nov 110 111 0,0 0,0 0,0 0,1 Dec 115 116 0,0 0,0 0,0 0,1 Jan 115 116 0,0 0,0 0,0 0,1 Feb 116 116 0,0 0,0 0,0 0,1 Mar 115 115 0,0 0,0 0,0 0,2 Apr 114 114 0,0 0,0 0,0 0,2 May 113 112 0,0 0,0 0,0 0,2 Jun 112 111 0,0 0,0 0,0 0,2 Jul 111 110 0,0 0,0 0,0 0,2 Aug 110 108 0,0 0,0 0,1 0,2 Sep 109 107 0,0 0,0 0,1 0,2 Oct 108 106 0,0 0,0 0,1 0,2 Nov 107 105 0,0 0,0 0,1 0,2 Dec 106 103 0,0 0,0 0,1 0,2 Jan 105 102 0,0 0,0 0,1 0,2 Feb 104 101 0,0 0,0 0,1 0,2 Mar 103 100 0,0 0,0 0,1 0,2 Apr 100 97 0,0 0,0 0,1 0,2 May 100 97 0,0 0,0 0,1 0,2 Jun 99 96 0,0 0,0 0,1 0,3 Jul 98 95 0,0 0,0 0,1 0,3 Aug 97 94 0,0 0,0 0,1 0,3 granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 2029 2030 2031 Sep 96 93 0,0 0,0 0,1 0,3 Oct 94 91 0,0 0,0 0,1 0,3 Nov 93 90 0,0 0,0 0,1 0,3 Dec 92 89 0,0 0,0 0,1 0,3 Jan 92 88 0,0 0,0 0,1 0,3 Feb 91 87 0,0 0,0 0,1 0,3 Mar 90 86 0,0 0,0 0,1 0,3 Apr 89 85 0,0 0,0 0,1 0,3 May 88 84 0,0 0,0 0,1 0,3 Jun 88 83 0,0 0,0 0,1 0,3 Jul 86 81 0,0 0,0 0,1 0,3 Aug 86 81 0,0 0,0 0,1 0,3 Sep 85 80 0,0 0,0 0,1 0,3 Oct 84 79 0,0 0,0 0,1 0,3 Nov 84 79 0,0 0,0 0,1 0,3 Dec 85 79 0,0 0,0 0,1 0,3 Jan 85 79 0,0 0,0 0,1 0,3 Feb 85 79 0,0 0,0 0,1 0,3 Mar 84 78 0,0 0,0 0,1 0,3 Apr 83 77 0,0 0,0 0,1 0,3 May 82 76 0,0 0,0 0,1 0,3 Jun 80 75 0,0 0,0 0,1 0,3 Jul 79 74 0,0 0,0 0,1 0,3 Aug 78 72 0,0 0,0 0,1 0,3 Sep 77 71 0,0 0,0 0,1 0,3 Oct 76 70 0,0 0,0 0,1 0,3 Nov 75 69 0,0 0,0 0,1 0,3 Dec 74 68 0,0 0,0 0,1 0,3 Jan 73 66 0,0 0,0 0,1 0,3 Feb 72 65 0,0 0,0 0,1 0,3 Mar 71 64 0,0 0,0 0,1 0,3 Apr 70 63 0,0 0,0 0,1 0,3 May 69 62 0,0 0,0 0,1 0,3 Jun 68 61 0,0 0,0 0,1 0,3 Jul 67 60 0,0 0,0 0,1 0,3 Aug 67 59 0,0 0,0 0,1 0,3 Sep 66 58 0,0 0,0 0,1 0,3 Oct 65 57 0,0 0,0 0,1 0,3 Nov 64 56 0,0 0,0 0,1 0,3 Dec 63 55 0,0 0,0 0,1 0,3 Table 10 – Production Profile data (Constrained Case) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} - Unconstrained case (max trunkline flowrate 270 MMSCFD) Well Gas Rate (MMSCFD) Well Cond Rate (STBD) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Well Water Rate (STBD) Year Month -3 -4 -3 -4 -3 -4 2026 2027 2028 Jan 0 0 0,0 0,0 0,0 0,0 Feb 0 0 0,0 0,0 0,0 0,0 Mar 0 0 0,0 0,0 0,0 0,0 Apr 0 0 0,0 0,0 0,0 0,0 May 0 0 0,0 0,0 0,0 0,0 Jun 0 0 0,0 0,0 0,0 0,0 Jul 0 0 0,0 0,0 0,0 0,0 Aug 6 6 0,0 0,0 0,0 0,0 Sep 108 108 0,0 0,0 0,0 0,0 Oct 107 107 0,0 0,0 0,0 0,1 Nov 110 111 0,0 0,0 0,0 0,1 Dec 115 116 0,0 0,0 0,0 0,1 Jan 119 120 0,0 0,0 0,0 0,1 Feb 122 122 0,0 0,0 0,0 0,2 Mar 125 125 0,0 0,0 0,0 0,2 Apr 129 128 0,0 0,0 0,0 0,2 May 133 132 0,0 0,0 0,1 0,2 Jun 131 130 0,0 0,0 0,1 0,3 Jul 129 127 0,0 0,0 0,1 0,3 Aug 126 124 0,0 0,0 0,1 0,3 Sep 124 122 0,0 0,0 0,1 0,3 Oct 122 120 0,0 0,0 0,1 0,3 Nov 120 117 0,0 0,0 0,1 0,3 Dec 118 115 0,0 0,0 0,1 0,3 Jan 116 113 0,0 0,0 0,1 0,3 Feb 114 111 0,0 0,0 0,1 0,3 Mar 112 109 0,0 0,0 0,1 0,3 Apr 111 107 0,0 0,0 0,1 0,3 May 109 106 0,0 0,0 0,1 0,3 Jun 107 104 0,0 0,0 0,1 0,3 Jul 106 102 0,0 0,0 0,1 0,3 Aug 104 100 0,0 0,0 0,1 0,3 Sep 103 99 0,0 0,0 0,1 0,3 Oct 101 97 0,0 0,0 0,1 0,3 Nov 100 95 0,0 0,0 0,1 0,3 Dec 98 94 0,0 0,0 0,1 0,3 granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 2029 2030 2031 Jan 97 92 0,0 0,0 0,1 0,3 Feb 96 91 0,0 0,0 0,1 0,3 Mar 96 91 0,0 0,0 0,1 0,3 Apr 94 90 0,0 0,0 0,1 0,3 May 93 88 0,0 0,0 0,1 0,3 Jun 92 87 0,0 0,0 0,1 0,3 Jul 90 85 0,0 0,0 0,1 0,3 Aug 89 84 0,0 0,0 0,1 0,3 Sep 88 83 0,0 0,0 0,1 0,3 Oct 87 82 0,0 0,0 0,1 0,3 Nov 86 81 0,0 0,0 0,1 0,3 Dec 84 80 0,0 0,0 0,1 0,3 Jan 83 79 0,0 0,0 0,1 0,3 Feb 82 77 0,0 0,0 0,1 0,3 Mar 81 76 0,0 0,0 0,1 0,3 Apr 80 75 0,0 0,0 0,1 0,3 May 79 74 0,0 0,0 0,1 0,3 Jun 78 73 0,0 0,0 0,1 0,3 Jul 77 72 0,0 0,0 0,1 0,3 Aug 76 70 0,0 0,0 0,1 0,3 Sep 75 69 0,0 0,0 0,1 0,3 Oct 74 68 0,0 0,0 0,1 0,3 Nov 73 67 0,0 0,0 0,1 0,3 Dec 72 66 0,0 0,0 0,1 0,3 Jan 71 65 0,0 0,0 0,1 0,3 Feb 70 64 0,0 0,0 0,1 0,3 Mar 69 63 0,0 0,0 0,1 0,3 Apr 69 62 0,0 0,0 0,1 0,3 May 68 61 0,0 0,0 0,1 0,3 Jun 67 60 0,0 0,0 0,1 0,3 Jul 66 59 0,0 0,0 0,1 0,3 Aug 65 58 0,0 0,0 0,1 0,3 Sep 65 58 0,0 0,0 0,1 0,3 Oct 64 57 0,0 0,0 0,1 0,3 Nov 63 56 0,0 0,0 0,1 0,3 Dec 62 55 0,0 0,0 0,1 0,3 Dec 0 0 0,0 0,0 0,0 0,0 Table 11 – Production Profile data (Unconstrained Case) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 8 DRILLING & COMPLETIONS 8.1 Drilling and Completions overview development considers the drilling of two wells: Ø -3 Ø -4 8.2 Wells targets coordinates The following table resumes the preliminary Wellheads coordinates as per [18]. Ø PROJECT-3 Water depth RKB elevation Sea Bed (from RKB) (m) (m) (m) 811 25 836 Well Head coordinates (Indonesia Offshore – PROJECT-3 Expl. Case “b”) Northing (m) South: 9,852,056 Easting (m) East: 583,427 Latitude (y): 1° 20' 18.163" S Longitude (x): 117° 44' 59.719" E Geodetic System: Universal Transverse Mercator Geodetic Datum: WGS 1984 MAP Zone: Zone 50 S (114 E to 120 E) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Ø PROJECT-4 Water depth RKB elevation Sea Bed (from RKB) (m) (m) (m) 1103 29 1128 Well Head coordinates (Indonesia Offshore - -4) Northing (m) South: 9,851,286 Easting (m) East: 585,820 Latitude (y): 1° 20' 43.223" S Longitude (x): 117° 46' 17.159" E Geodetic System: Universal Transverse Mercator Geodetic Datum: WGS 1984 MAP Zone: Zone 50 S (114 E to 120 E) 8.3 Preliminary Casing Design A preliminary material selection, considering that a pore pressure study is not still available, we can chose like casing / liner string the same material and size already used for Merakes & Jangkrik projects and to consider what has been already “planned / mentioned” within Gas Brand IDD (Indonesia Deepwater Development) Project, POD June 2018. Size (Inches) Steel grade ( // ) Wall thikness (Inches) CASING SETTING DEPTH "PROJECT-3" (proposed). Weight (Lb/ft) Connection type ( // ) Csg shoe depth (TVDss) (m) Csg shoe depth (TVD) (m) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Csg shoe depth (MD) (m) Csg / Liner Lenght (MD) (m) Quick 36 X52 1,5 552,7 881 906 906 70 Connector Quick 20 X56 0,812 166,4 Connector 1461 1486 1486 650 13,625 P110 0,625 88,2 Premium 2075 2100 2171 1335 10,75 T95/P110 0.595 65.7 Premium 2674 2699 3178 1127 10-3/4 Liner TOL (TVDss): 1989m TOL (TVD): 2014m TOL (MD): 2051m -3 Csg /Lnr setting depth & Type Total liner length: 1127m MD Liner Overlap: 120m MD granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Size (Inches) Steel grade ( // ) Wall thikness (Inches) CASING SETTING DEPTH "PROJECT-4" (proposed). Weight (Lb/ft) 36 X52 1,5 552,7 20 X56 0,812 166,4 Connectio n type ( // ) Quick Connector Quick Connector Csg shoe depth (TVDss) (m) Csg shoe depth (TVD) (m) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Csg shoe depth (MD) (m) Casing / Liner Lenght (MD) (m) 1173.48 1198 1198 70 1703.48 1728 1728 600 13,625 P110 0,625 88,2 Premium 2225 2250 2272 1144 10,75 T95/P110 0.595 53,5 Premium 2844 2869 3302 1150 7 P110 0,453 32 Premium 3353 3378 4205 1023 Note: The contingency of 7” Liner will be set only to cover exploration tail incase needed. 10-3/4 Liner 7 Liner TOL (TVDss): 2120m TOL (TVDss): 2777m TOL (TVD): 2145m TOL (TVD): 2802m TOL (MD): 2152m TOL (MD): 3182m -4 Csg /Lnr setting depth & Type Total liner length: 1150m MD Total liner length: 1023m MD Liner Overlap: 120m MD Liner Overlap: 120m MD Based on experience, no H2S is not present in the field. Fluid sampling was obtained using the MDT tool in both the Gendalo-4 and -1 wellbores. All samples obtained using the MDT tool were contaminated with synthetic oil-based drilling fluids, resulting in questionable measurements of condensate yield. Since there are no specific lab analysis reports of the MDT samples collected for the secondary reservoirs in (3140/50 & 3170), the 3130 fluid properties can be assumed for the secondary reservoirs. The properties from sample # JFL2002074 are shown in table below. In order to estimate condensate yield, the observed MDT pressure gradient in the 3140/50 was matched using a fluid density calculation. The technique was found not to be sensitive to condensate gravity and results in condensate yield estimation of 2 bbl / mmcf. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} On -1 fluid samples indicate the need for corrosion resistant alloys in the flow-wetted tubulars. Main contributor on corrosion potential on field was CO2 in formation. High partial pressure value shows the requirement of corrosive resistance material on flow wetted including 9 ⅝” production liner and 5 ½“ production tubing. The use of 13 Cr (or Super 13 Cr) martensitic stainless steel could be a solution to prevent the corrosion phenomenon. For the casing above packer carbon or low alloy steel material is a suitable. It can be selected among sour service materials, according to mechanical strength required for the casing application according to API 5CT. 8.4 Completion Schematics The design has been prepared in compliance with “Completion Design Procedure” (STAP-P- 1- M-26543). The following considerations have been taken into account in the current completion design: - Respect of HSE regulations. - Capability to deliver forecasted hydrocarbon production rates. - Capability to inject adequate water and gas rates. - Safety of operations and reliability of equipment. - Longevity for the full wells lifetime. - Operational time optimization due to high daily rig cost. - Simplicity of design with standard and field proven technology. - Equipment cost and delivery time reduction achieved by standardization. - Capability to cope with the worst anticipated operating loads and environment. - In compliance with International Standards and good oilfield practices. Three well completion typologies will be evaluated: 1) 3 (scenario 4) well would be completed in two production zones with CHFP in 10¾” liner and smart upper completion. 2) 4 well would be completed with 1 CHFP inside 10¾” liner with posibility to split into 2 stack. Upper smart completion will be also available incase required. Current completion strategy designed to maximize well deliverability by upsize the completion size to allow higher gas rate in 10-3/4” liner system compared with 9-5/8” liner system. Other options can be further evaluated at later stage of the project. 8.5 Preliminary Metallurgy and Elastomers Selection No dedicated completion material study has been commissioned yet. However 13Cr material will be considered as most likely for the analogy with other indonesian project already developed (Jangkrik, Merakes). This consideration will be apllied also for cost evaluation. This aspect will be further analized in the followig step of the project. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 9 FLUID DATA AND PRODUCTION CHEMISTRY 9.1 Reservoir Fluid Properties Due to expected high pressure and relatively low temperature during both normal and transient operations, fluids are expected to be susceptible to hydrate formation. Hydrates formation shall be avoided in all scenarios by means of continuous hydrates inhibitor injection (Lean MEG solution MEG 80%wt). Similar hydrate prevention strategy as for JKK and Merakes field is considered. MeOH is injected in start-up / restart due to avoid low temperature issues and hydrate formation risks. No asphaltenes, foaming and emulsion formations are assumed present in the reservoir fluids. Scale formation is assumed present as for JKK and Merakes reservoir fluids. 9.2 Reservoir Fluid Composition For the reservoir fluid composition, ref. to 7.2. 9.3 Scale Potential Scale formation is assumed present as for JKK and Merakes reservoir fluids. 9.4 Wax Formation and Rheology See 9.1, no waxes, foaming and emulsion formations are expected in the reservoir fluid. 9.5 Hydrate Equilibrium Curves Hydrates curve have been calculated with the reservoir fluid composition reported in section 7.2 saturated at reservoir conditions (30 bar, 74°C). Figure 5: - Hydrate formation curves This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 9.6 Hydrogen Sulphide The reservoir fluid is expected to be H2S free. 9.7 Asphaltenes No asphaltenes are expected in the reservoir fluid. 9.8 Material Selection As no data are available on water analysis, the same chemical composition as for JKNE will be considered with as main constituent used for material selection carbonate with a content equal to 105 meq/l. 9.8.1 CO2 Corrosion Wet CO2 corrosion is generally referred as ‘sweet corrosion’ when H2S is absent. When CO2 is present in the gas phase, any water in contact with this gas will dissolve CO2 to a concentration proportional to the partial pressure pCO2, of the CO2 in the gas and temperature. The overall philosophy used in the selection of materials and corrosion control systems is based on conditions of operation with adequate integrity while minimizing capital costs and maintaining schedule for fabrication. Corrosion shall be mitigated by sufficient application or combination of the following methods: • Materials selection (corrosion allowance) • Coatings • Chemical treatment • Cathodic protection • Corrosion control/monitoring The corrosion allowances for pipelines shall be specified with regard to the corrosion rates calculated after taking into account the effectiveness of inhibition, environmental conditioning and design life. Generally, process and corrosive utilities equipment and piping shall be specified with a minimum 3.0 mm corrosion allowance and maximum of 6.0 mm corrosion allowance while pipeline can be maximum 8 or 10 mm. Calculated unhibited corrosion rate is 0.9 mm/yr equivalent with 8.84 mm reduction thickness during 20 years design lifetime. By injecting corrosion inhibitor as per document Internal Corrosion - Fluids Classification and Corrosion Parameters Definition Ref. Doc. 02555.VAR.COR.PRG which may be assumed that inhibition can decrease the corrosion rate to 0.1 mm/year Efficiency inhibitor will use formula as per standard. Corr = (CRinhib x lifetime x availability) + CRunhib x lifetime x un-availability = (0.1 x 25 x 0.9) + (CRunhib x 25 x 0.1) Infield Pipeline, Formation Water Case Description Value Unit max. corrosion rate 2.0 mm/y Inhibited corrosion rate 0.2 mm/y total corrosion allowance with 95% CI 4.35 mm availability (15 years) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} The result of evaluation for considered only water condensed can be summarized as below. Infield Pipeline, Condensed Water Case Description Value Unit max. corrosion rate 2.8 mm/y Inhibited corrosion rate 0.2 mm/y total corrosion allowance with 95% CI 4.95 mm availability (15 years)s Based on the all above cases, material selection for flowline is calculated as CS + 5 mm CA + >95% of corrosion inhibitor availability. 9.9 Flow Assurance Issues For Flow Assurance details please see ref. 9.1. 9.10 Flowing And Shut In Condition 9.10.1 Flowing Well Head Pressure The flowing well head pressure of considered for the analyses are reported below. Grey cells highlight that the wells or cluster is closed. Expected Mode HP mode LP mode Date PROJECT PROJECT-4 PROJECT-3 Sep-26 206 196 May-27 152 134 Jun-28 125 110 Dec-29 97 85 Jun-30 90 80 Jun-31 78 66 Jun-32 68 57 Jun-33 61 51 Jun-34 56 46 Jun-35 47 48 Dec-36 38 40 Jan-37 46 Table 12 – Unconstrained case - FTHP This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 9.10.2 Flowing Well Head Temperature The flowing well head temperature of wells considered for the analyses are reported below. The two tables report the flowing temperature upstream and downstream PCVs: Flowing Wellhead Temperature Upstream PCV Date -4 -3 Sep-26 59.0 60.0 May-27 55.0 55.0 Jun-28 54.0 54.0 Dec-29 54.0 54.0 Jun-30 54.0 54.0 Jun-31 54.0 53.0 Jun-32 54.0 54.0 Jun-33 54.0 54.0 Jun-34 53.0 54.0 Jun-35 42.0 54.0 Dec-36 4.0 53.0 Jan-37 4.0 47.0 Table 13 – Unconstrained Case – FTHT u/s PCV Flowing Wellhead Temperature Downstream PCV Date -4 -3 Sep-26 41 41 May-27 50 52 Jun-28 51 52 Dec-29 53 54 Jun-30 54 54 Jun-31 52 53 Jun-32 53 53 Jun-33 53 54 Jun-34 53 53 Jun-35 42 53 Dec-36 4 53 Jan-37 4 46 Table 14 - Unconstrained Case – FTHT d/s PCV 9.10.3 Topside Arrival Pressure/Temperature As per base case, is kept in production in Hybrid mode (HP or LP) as detailed in the previous chapters. The fluid temperature at FPU arrival is expected in the range -2-to-10°C, the lorelated to high flowrate. 9.10.3.1 Operating Cases Base Case - with single flowline connection (Figure 6): the n.2 new wells are tied- back to Jangkrik trunkline 1 by means of 12” new subsea production flowline. Jangkrik Production from Cluster 1 will be sent to Jangkrik Cluster 3. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 9.10.3.2 Inlet Flowrate FPU JKK Figure 6 – Field Development The following production cases are selected for design purposes (Table 15) and with the aim to verify the existing FPU capacities. Field TKLs Flowrate (MMSCFD) Inlet Pressure (barg) This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Slug Catcher 223.6 40 Jangrkik TKL1 Jangkrik 0 40 North East Jangkrik TKL2 11.6 25 TKL3 45.3 25 Jangkrik NorthEast TKL4 9.71 25 Merakes/Merakes East TKL5 9.71 25 TKL6 190 25 TKL7 190 25 Jangkrik Main Merakes East 87.5 MMSCFD Merakes 292.6 MMSCFD - Table 15: STRATEGIC PLAN (MKSE SU 1-Jul-25, PROJECT SU 1-Mar-25) with 2.8%DT JKK/JNE MKS PROJECT MKSE Flowrate [MMSCFD] 76.37 292.6 223.6 87.5 granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Slug Catchers Capacity: HP Mode LP Mode MMSCFD MMSCFD JKK Main SC 463 342 JKK NE SC 309 228 Merakes SC 450 400 For fields the flowrates for gas, condensate and total free water @Jangkrik FPU inlet have been extracted from the production profiles received by HQ, where the gas, condensate and water flowrates used in the “Sterategic Case” (i.e. the Dual Mode Case) with a maximum export capacity of about 750 MMSCFD @FPU inlet and with producing 230 MMSCFD as the maximum plateau in HP mode and 170MMSCFD plateau in LP mode, which Low pressure with an arrival pressure of 25 barg and High Pressure with an arrival pressure of 40 barg on FPU inlet. In the following Table 16, shown the gas flowrate in the various trunkline of JKK FPU from different case study and debottlenecking projects. HP = 40 barg at FPU inlet LP = 25 barg @ FPU Inlet Table 16: Design cases from debottlenecking projects • Case 1: adjusted based on received profiles, January 2024 (total production 616 MMSCFD) • Case 2: smoothly adjusted based on received profiles, July 2025 (total production 746 MMSCFD) • Case 3: as per received profiles, February 2028. Requested only verification of inlet facilities (TKL-1 and Slug Catcher) • Case 4: as per received profiles, March 2023. It should be covered by Case 2. 9.10.3.3 Target LP Max Flowrate q 616 MMSCFD max flow in LP based on production profile q Maximum production with minor modifications • 600 MMSCFD @ LP • Based on max seawater flowrate of 7500 m3/h q 720 MMSCFD Target FPU capacity in LP for DBN Verification • According to previous study, the same modifications are required above 600 MMSCFD in LP up to 720 MMSCFD This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Seawater consumption (from Saipem study): ~ 8400 m3/h 9.11 Product Specification 9.11.1 Produced Oil Specification is connected to existing Jangkrik FPU and then the same specification on gas and condensates of Jangkrik project applies. So following specifications for Gas and Condensate are assumed to be valid also for , based on Process Basis of Design for Jangkrik FPU. Properties Specs HC Dew Point 12°C @ any pressure from 52 barg up to maximum export pressure; Water Dew Point 9°C @ maximum export pressure Associated water content 9.11.2Produced Treated Water 9 lb/MMSCF Table 17: Produced Specifications Table 18: Sale Condensate Specifications The FPU is designed to handle, treat and dispose the produced water and any other waste water generated by the process and utility units aboard the FPU. A dedicated Produced Water Treatment unit of about 1150 Sbbl/d is available. Treated water discharged overboard shall meet the following specifications: • Maximum HC content: 15 ppmv (30 days average), 42 ppmv maximum daily peak • Maximum MEG content: 3500 ppmv • Maximum discharge temperature: 40°C Discharged water shall be continuously metered and its quality continuously monitored in line with local environmental regulations. On-line analysis shall be based on Indonesian national standard SNI 06-6989.10-2004. In the event that the water quality requirements are not met, produced water shall be automatically routed to the slop oil tank. A dedicated hull storage of 1300 m 3 is provided for Treated Water. 9.11.3 H2S Content The reservoir fluid is expected to be H2S free. Properties Specs RVP ≤ 11 psia TVP @ 40°C ≤ 13 psia Water Content < 0.1% vol. BSW < 10 PTB This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 9.11.4 CO2 Content The reservoir fluid from , as evident from the reservoir fluid compositions in Table 9, shows a CO2 content of 0.92 mol %. 9.12 Field Flowrates for Design Purpose The following production cases are selected for design purposes (Table 19) and with the aim to verify the existing FPU capacities Fluid HP Inlet Gas [MMSCFD] 223.6 Inlet Condensate [Sbbl/d] 1303.5 Inlet Water [Sbbl/d] 0.68 Table 19 - Development - Design cases For field the flowrates for gas, condensate and total free water @Jangkrik FPU inlet have been extracted from the production profiles received by Reservoir HQ. The saturation water and MEG associated to Jangkrik has been prorated according to the new gas flowrates taking into by assuming the same corresponding pro-rating values used for Jangkrik Main. 10 FACILITIES 10.1 Subsea, Umbilical and Flowlines In the following, a description of the subsea system (incl. umbilical and subsea structures) and flexible flowline system foreseen for the field is provided. 10.1.1 FPU For a FPU Process Description, refer to [22]. 10.1.2 Design Life The design life of the subsea production and control system shall be 20 years. 10.1.3 Maximum Water Depth The whole subsea system shall be designed for 1.200m of water depth. 10.1.4 Main Subsea Equipment A preliminary subsea equipment list and related design data is provided in the below tables. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Item Quantity Production Xmas Tree HIPPS System 1 Design Pressure 2 10.000 psi (i) 270 Bar Header from HBV1 (valve not included) to inboard connector, Header from TIV1 (valve not included) to inboard connector & adjoining Hot Stab lines; (ii) 421 Bar remaining parts of Header, header valves and chemical injection lines This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. Design Temperature Upstream the choke: -18/+121 °C (1) Downstream the choke (included): -48/+121 °C -20/+70°C granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} TEE Structure 1 Subsea Structure 4 Hub UTA Table 20: Preliminary list of main subsea equipment (1) As per Merakes XTR (2) MEG pump design pressure = 340 barg (PSV set point). Including Pressure head at 1200m is therefore equal to 340 barg + 130bar = 470 bar. See Ref. [32] for Design pressure definition due to MEG packing condition. (3) 3&2&4WHSIP*1.1=242.2*1.1=270bar (4) DT=Max operating (55Deg) plus 15Deg of contingency (5) A new FLET is foreseen for connecting the Jangkrik Cluster 1 to Jangkrik Cluster 3 already existing FLET 1, through a new Interconnecting Line HIPPS valve set point max flowing plus contingency = 110bar Note: As contingency approach, the DP of 7500psi is considering potential closure of Subsea Structure valve by mistake during installation of operation phase. As consequence, the DP of Subsea Structure and welljumper is driven by MEG packing (see note (2)). 10.1.5 Umbilicals 1 1-off – Project UMB1 UTA A 1-off – Project UMB1 UTA B 1-off – Project UMB2 UTA A 1-off – Project UMB2 UTA B & test port lines. 270 bar for header, 650 for branch up to branch valve (valve included) 520 bar for all parts of the structure exception made for the header connectors (270 bar) In order to control the Subsea Production System a dedicated electro-hydraulic umbilical system will be installed. The umbilical will supply to Subsea Production System equipment the hydraulic power, chemicals, electrical power and control signals, see ref. [12]. The following scenario will be considered This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. -20/+70°C -29/+70°C FLET 1 TBD TBD granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Umbilical from JKK Cluster 1: This scenario considers using the existing JKK Main UMB 1 to control Field. An assessment was performed by subsea control vendor (refer to feasibility study for details). Errore. L'origine riferimento non è stata trovata.For such scenario the network of UMBILICAL consist in: • UMB1: flying leads connect UMB1 UTA A to JKK Cluster 1 SDU and to HIPPS, all located near JKK Cluster 1. UMB1 UTA B connects to 3b and to Project UMB2 UTA A via flying leads. • UMB2: UMB2 is connected in daisy-chain to UMB1 via flying leads. UMB2 UTA B connects to 4 Xtree via flying leads. Block Diagram for this scenario is in Ref [2]. For further details of the umbilical system refer to Ref [31]. In order to benefit from existing design and equipment, the spare umbilical of Merakes infield UM1C will be used for UMB2.The umbilical UMB1 shall be designed to support the control of the HIPPS module, 3b and 4. The base case is to avoid additional design variant, therefore to use same design as UMB2 . The aim is to to minimize customized design and engineering activities for project; however, further optimisation may be evaluated for the UMB1 design,e.g. 1-off 1.5” MEG. 10.1.6 Control System Description Each Xtree and HIPPS will be controlled by its dedicated SCM. Flying leads will distribute control to the SCMs frm the UTAs to the host structures. The subsea control system shall be compatible with the existing subsea control system and be designed in accordance with company standard 18010.ENG.STA.STD; HIPPS shall be designed based on requirements stated inside 28746.ENG.STA.STD. Communication type will be “Communications On Power” (COPS) and the hydraulic system will be closed loop with a return line from subsea to surface. The susbsea system will be controlled topside by the existing Jangkrik topside control system. Modifications to the existing topside facilities will be required and include software and hardware updates. Hardware updates may be carried out one channel at a time and therefore could potentially be executed without need to shutdown JKK cluster 1. However, software updates on the topside system may require production shutdown. For more details see [30][31]. 10.1.7 Flowlines System Flexible pipeline shall be considered for the development of the development project. The below table includes all the design input to be consiered for the flexible pipeline design and routing analysis. Preliminary indications on flexible jumpers are also included. Standard 23020.ENG.SSE.STD International Code API 17B API 17J Inside Diameter for flowline 1 and 2 12” – 304.8 mm Inside Diameter for flowline 3 11.5” – 292 mm (*) Inside Diameter for Flexible Jumper (**) 12” – 304.8 mm This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Inside Diameter for Well Jumpers 8” ID Inside Diameter for Interconnecting Flowline 8” ID Design Temperature 70°C Design Pressure for flexible flowline 1, 2 270 bar Interconnecting flowline 205 bar Design Pressure for Flexible flowline 3 (*) 520 bar Design Pressure for flexible jumper (**) 205 bar Water depth 1200 mt (*)Spare 11.5” flexible line will be used from Merakes Project. (**) Flexible jumper will be needed to connect the existing JKK manifold 1 with the new FLET. Use of flexible solution has been evaluated during the concept selection phase in terms of mechanical response to the required service conditions and to the foreseen water depth. Flexible pipeline has been also compared against the rigid solution in terms of cost, schedule and installability. Flexible jumpers are assumed to be needed also between 2 and 4 wells and relevant structure: Flexible Well Jumper Design Pressure 520 bar Flexible Well Jumper Design Temperature 70 °C Flexible Well Jumper Length / nr. ~90 mt / 2 11 HEALTH, SAFETY, ENVIRONMENT The project is developed in compliance with Indonesia and Upstream HSE policies, referring to ISO 14001 requirements for Environmental Management Systems, ISO 45001 and OHSAS 18001 for Occupational Health and Safety Management Systems. Indonesia HSE Policy are considered as the reference to define HSE Project Requirements as well as the compliance to the Upstream Standards and 10 HSE policies. HSE design criteria to be applied to the present Concept Definition Phase are reported in the preliminary Health, Safety and Environmental (HSE) Philosophy. The document aims to ensure an inherently safe design, in order to: • Minimize the potential of hazardous occurrences; • Minimize the risk and consequences of an accidental event; • Ensure a safe working environment for personnel; • Ensure adequate means of escape in case of emergency; • Provide sufficient safety devices and redundancy to detect, isolate and minimize uncontrolled releases of flammable and toxic fluids; • Provide appropriate fire protection systems to rapidly bring under control and extinguish any reasonably foreseeable fire which could develop during normal operations; • Minimize the potential pollution of the environment. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} The project development shall be supported by an HSE design based on a formal risk-based assessment process (e.g. HAZID, HAZOP, ESHIA, other safety studies). The aim of the formal safety assessment process is to ensure that all potential hazards have been identified, associated risks assessed, and measures taken to eliminate, reduce, control or mitigate the consequences of those hazards. 11.1 Safety Criteria The objectives of the HSE Criteria are to: • minimise the risk and consequences of an accidental event; • minimise the potential for hazardous occurrences; • maximise the benefits of protection measures; • provide sufficient safety devices and redundancy to isolate and minimise uncontrolled releases; • provide appropriate fire protection systems to control any reasonably foreseeable fire which could develop during normal operations; • ensure adequate means of escape and rescue are provided from all areas; • minimise the potential for pollution of the environment from accidental spills, venting or flaring of hazardous materials; • ensure that all operational hazards and risks are minimised during construction including that in existing plant. The goal of a safe facility design is to eliminate the high (intolerable) risks and to reduce the medium (tolerable) risks to a level that can be demonstrated to be ALARP. This is carried out by reducing the probability of occurrence of events and minimizing their consequences. The main principles for safe facilities design and operation are: • support for design decisions making based on sound safety reasoning; • containment of hydrocarbons and prevention of hydrocarbon ignition; • minimization of the chances of ignition; • prevention of fire escalation and gas monitoring; • provision of personnel protection and escape. 11.2 Health Considerations The Project will meet the health and regulatory compliance requirements and assure the appropriate protection of worker health (employees and Contractors) from adverse health effects that may result from the design, construction, commissioning and operations activities. As per above, the health related risk based approach will include the following objectives: • Identify and evaluate health hazards/risks (e.g., occupational health risks / exposures, vector-borne disease, infectious disease, accommodations, food and water, medical support, etc.). • Mitigate health hazards/risks. • Communicate health hazard/risk information. • Define staff medical fitness for duty evaluation programs. • Assess health of potentially exposed workers. • Verify satisfactory health management through health inspections and surveillance including industrial hygiene management. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} In addition to the Project health specifications which will be further developed during the next Project phase, the following considerations, and not limited to, shall also be further defined and incorporated into facility design: 1. Facility Noise Sound Level Design Criteria. 2. Medevac arrangements. 3. Emergency Shower and Eyewash Facilities. 4. Design of Hazardous Materials Storage and Handling Facility. 11.3 SIMOPS Simultaneous Operations (SIMOPS) refers to the multiple activities such as continuous production of hydrocarbons (oil or gas), executed concurrently, with drilling, maintenance, construction, commissioning or well operations in any existing oil and gas facility. The primary benefits of carrying out simultaneous operations whilst maintaining production are the economic incentives within controllable risk, thus minimising the deferment of hydrocarbon production. The interaction between the multiple activities tends to result in an increased operational complexity and higher level of risk. This is because during each SIMOPS, more than one activity being conducted concurrently may result in the introduction of additional risk and increased probability of failure to control the hazard associated with these risks. For example, presence of additional ignition sources from hot work activities such as cutting, welding, etc., would increase the probability of ignition should there be a hydrocarbon leak on the process facility nearby. 11.4 RISK IDENTIFICATION During current Project Phase the following studies will be carried on: - HAZID Analisys: HAZID is a structured review technique for the early identification of all significant hazards associated with the particular activity under consideration. HAZID is carried out by a systematic analysis of all the potential external threats with the potential to generate health, safety, environmental, asset and reputational risks. - HAZOP Analisys: HAZOP studies shall be used to analyze the design of operating facilities, new facilities or modifications to process and utility systems as a way of rigorously and systematically checking the design for safety, operability and conformity with codes of practice. All these sessions have the aim to identify as soon as possible all risks associated to the production phase that can have impact principally on Safety, Environmental and Asset. Risk matrix that will be used for risk ranking (when required) as reported below: This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} Table 21: Basic risk matrix (full qualitative approach) All reccomendations arisen during sessions will generate an action that will be in charge to the dedicated department. All actions shall be correctly managed before the end of current Project phase, with evidence of their implementation. 11.5 Environmental, Social and Health Impact Assessment During FEED Project phase a Environmental, Social and Health Impact Assessment SoW has been produced. The outcomes of the study will be shared with Contractor for design purposes. This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} 12 GHG EMISSION AND MITIGATION OF CLIMATE CHANGE EFFECTS: The Company has a strong commitment to reduce GHG emissions in business initiatives: the impact shall be minimized deploying proper technologies and taking into account an optimization on the overall project production life. This shall be achieved through appropriate measures, depending on the specific project characteristics. In particular: • No routine flaring is allowed at any stage of the project. • Non-routine flaring shall be minimized. • Metering systems shall be installed for all gas streams. • Continuous CO2 venting from fluids nor Methane venting contained is allowed at any time of production. • Stationary combustion emissions shall be minimized always preferring low energy intensity processes and deploying high efficiency fuel gas-based power generation systems or evaluating connection to local power network where feasible. 12.1 Water Management The minimum general requirements to be adhered to are as follows: • Reduction of the usage of water shall represent one of the main design criteria. Water re-use shall be preferable to recycle. Water recycle shall be preferable to water discharge. • Installation of flow meters for each water stream (input and output) shall be assured. Any discharge of water brought into contact with hydrocarbons, chemicals, and any potential source of contamination shall be routed to treatment system before final disposal. 13 REGULARITY AND OPERATION The Regularity and operation principles of Development Project aim at ensuring uninterrupted exploitation operations, maximizing the ergonomics of installation and minimizing operation life- cycle cost, assuring the asset integrity, reducing the risk of accident occurrence, minimizing worker exposure to risks and protecting the environment. The assurance will be achieved by having in place appropriate management control and engineering practices that meet the requirements of the Company, international standards and legal obligations and any other applicable national regulation (see also ref. [3]). Asset Life Cycle processes will be formalized in Development Management System (DMS) and Operation Management System (OMS), providing directions and requirements for all those activities of Development and Production processes involving Indonesia. The FPU will be permanently manned while a non continuous presence of workers is foreseen for the onshore facilities (i.e. unattended operations). The staff onboard the FPU will operate in turning shifts and will be accommodated in the LQ module that will include living room, recreation room, first aid facilities and a Helideck. In order to optimize the levels of the manning commensurate with the control technology adopted, the following criteria will be implemented: • Utilize support infrastructure to manage staffing levels synergies; • Ensure high levels of staff competence in all teams; This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. granularity=word contentanalysis={punctuationbreaks=false dehyphenate=false} layoutanalysis={tabledetect=0 layoutdetect=0} • Adopt empowerment approach to work; • Adopt suitable staff competence assurance and development methods; • Implement a contracting plan aimed to supplement staffing needs with external technical sources; • Take into consideration the local content requirements. 14 SIMOPS AND CONOPS REQUIREMENTS In this chapter all the specific requirements for SIMOPS and CONOPS coming from the development/project within or nearby existing or operating facilities or nearby other operations. SIMOPS It is preliminary considered that during the installation activities of EPCI facilities there is a risk that the following activities may be accomplished simultaneously: • Drilling and completion activities • Produciton from facilities already handed over to Company. CONOPS It is preliminary assumed that any FPU activty under EPCI scope will be performed simultaneously with FPU production. Further analysis will be made to deeper comprehend the criticality and the advantages of this solution and eventually propose alternative options. 15 ATTACHMENTS Annex 1 – Limits and Quality Standards This document is property of DRIMCO. It shall neither be shown to Third Parties not used for purposes other than those for which it has been sent. 0.00 0.00 0.00