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Draft- For discussion Purpose Only
Progress of Joint Feasibility Study forCO2-CCS Project in Indonesia
February, 2013
PERTAMINA
Marubeni Corporation
Arabian Oil Company, Ltd.
Mitsubishi Research Institute, Inc.
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Concept of CCS/EOR
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Subang Gas Field and Jatibarang Oil Field
Pipeline
Subang Gas Field Jatibarang Oil Field
Balongan Refinery
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1. G&G and Reservoir Study
2. Cost estimation for Surface Facilities
3. Planning of Pilot Test
4. Investigation of seismic monitoring for CO2 storage and
behavior
5. Investigation of CO2 Capture and Recovery fromRefinery
6. Investigation of law and tax system for the project
7. Feasibility of the Project and Future Schedule
8. Investigation on MRV/Assessment methodology forGHG emission
Contents of FS
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F-Layer
Jatibarang Volcanics
(From UTC)
G&G Study - Stratigraphy
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Seismic Re-interpretation
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G&G and Reservoir Modeling Study
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3D seismic re-interpretation
Re-construction of geological model
Reservoir simulation and future prediction for CO2 Storage
PHIE Distribution
(Sequential Gaussian Simulation)PHIE Distribution
(Sequential Gaussian Simulation)
F-Layer Volcanics-Layer
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CO2 Injection, Storage and Re-Injection
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CO2Capture
CO2 from
Subang
CO2
Recycle
F Volcanics
Subang Flow of CO2
CO2 Storage Volumeabout 11.4 x 10^6 tons/20years
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CO2 storage in Volcanics
Apr 2018
CO2 mole fraction in gas phase
Jan 2038
CO2 will be stored at higher structure,
will not leak beyond reservoir boundary.
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Design for Surface Facilities
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6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3
2 m oW o r k o v e r
6 m o n t h sTes t f o r F l a y e r
3 m oEva lua t i on
E IA Repo r t8 m o n t h s
We l l Dr i l l i n g(1 Injection Well
3 Producing Wells) 8 m o n t h sFac il i ty Co nstru ct io n T es t fo r Vo lo can ic s laye r
2013 2014 2015 2016
6 m o n t h sPrepa ra t i on
Pilot Test Planning
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Well Drilling Pattern
Injector
Producer
Pilot Test will be conducted to verify the results of FS such as theincreasing oil production and CO2 storage.
It is essential to proceed to the next step commercial phase.
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Facilities for Pilot Test
Test SeparatorLiquid Storage
Tank
Liquid Transfer
pump
Producer
Injector
Liquid CO2
Tank Lorry
Liquid CO2
Storage Tank
Injection
Pump
Flow Meter Heater
To Flare
To Existing Oil Line
Block Flow of CO2 CCS/EOR Pilot Test Facilities in Jatibarang Oil Field
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Seismic Tomography in Pilot Test
Vp-change
CO2 mol Sg after Injection
Inverted Vp-change
via Conventional-Tomography
Not inverted
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Pilot Test Operation Scheme
Joint Venture Companyor Joint Operation Scheme
Arabian OilCompany Ltd.
Contractor
CO2 EOR CCSPlant
Pilot Test
PERTAMINA
Construction
Government of
INDONESIA
Government of
JAPAN
MarubeniCorporation
Support Support
Investorsor
Partners
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Location of CO2 Emission Sources
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Thermal Power Plant and Refinery
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CO2 Recovery from Refinery
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Based on the information and data during site survey at Balongan Refinery, we
defined the flue gas sources in which CO2 can be effectively recovered.As a result, we are planning to recover CO2 in flue gas emitted from thefollowing equipment.
- Furnace upstream of the atmospheric distillation unit- Hydrogen production unit- Boilers
We are investigating the most suitable process to recover CO2 emitted fromabove equipment and the number of trains of CO2 recovery unit to be installed.
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Project Future Schedule
2013-2015- Test well drilling and Facilities construction
Preliminary FS (for F layer) (2010-2011 METI FS)
Secondary FS (for F and V layers) (2011-2012 NEDO FS)
Pilot Test
Facility Construction and Well Drilling2016-2018
- Commercial Facility and Pipeline Construction- New Well Drilling for Jatibarang field
Start CO2 EOR/CCS
2012-2013 NEDO FSThird FS (Reservoir Study, Pilot TestPlanning, CO2 Capture from Refinery andCO2 Monitoring by Seismic methods)
2018- Increase Crude Oil and Decrease CO2 Emission
Apply CO2 EOR/CCS to other oil and gas fields
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CMP7 adopted the modalities and procedures for CCS in CDM(here in after CCS CDM M&P). Appendix B of CCS CDM M&Pprovides Additional requirements for CCS under the CDMincluding followings,
Site characterization with numerical three-dimensional static earth model
Risk and safety assessment and management
Detection and estimation of the CO2 seepage
The proposed methodology defines specific methods regardingthese requirements.
Major reference documents;
CCS CDM M&P(CMP7)
IPCC Special Report for CCS
Past proposed CDM methodologies
Best practice manuals by European commissionBest practice manuals by US NETL
Guidelines and latest practice by Japanese Government
ProposedCCS Methodology under the JCM
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Eligibility Criteria
Criteria References
Criterion1
The project shall capture, collect and store anthropogenic CO2,such as CO2 separated from gas/oil production or CO2emissions from fossil-fired power plants.
IPCC SRCCS
Criterion2
The project shall have CO2 injection into oil/gas field oraquifer (including enhanced recovery of oil and gas).
Criterion3
CO2 capture and storage shall be implemented in Indonesia.Besides, the selected storage site shall not be located ininternational waters.
CCS CDM M&P(CMP7)
Criterion4
Storage formation shall not be utilized in other projects.
Criterion5
Storage site shall not be suitable for potable water supply.
Criterion6
Storage site shall be selected appropriately by monitoreddata and CO2 injection simulation with numerical three-
dimensional static earth model (See following slide)Criterion7
Under the proposed or actual conditions of use, no significantrisk of seepage or risk to human health or the environmentexists(See following slide)
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Eligibility Criteria - criterion 6Characterization of the geological storage site
Characterization with individual monitoring results
Extracted from Best Practice for the Storage of CO2 in Saline Aquifers:
Observations and Guidelines from the SACS and CO2STORE Projects.
Parameters Criteria
Storage formation Depth >800m
Thickness >10m
Average Porosity >10%
Average Permeability >10mD
Cap rock formation Thickness >20m
1. Aggregation relevant data (Geological information, Geophysicalinformation, Geomechanical information, Geochemical information andHydrogeological information)
2. Establishing numerical three-dimensional earth model
3. Examining that injected CO2 will be stably held in the storage sitefor over 1000years.
Characterization with 3D dimensional model simulation
Extracted from IPCC Special Report for CCS, CCS CDM M&P(CMP7) and othermaterials.
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Eligibility Criteria - criterion 7Risk assessment and management
Risk and safety assessment
Extracted from IPCC Special Report for CCS, CCS CDM M&P(CMP7) and other
materials.Risks of serious environmental and health impacts are assumed to be induced byfollowing occasions.
a. containment failure of above-ground installations
b. seepage from subsurface zone
c. effects of potential induced seismicity or other geological impacts
The methodology defines methods to address these risks appropriately. Regarding risk b.above, it defines methods in line with IPCC Special Report for CCS (See bellow).
Potential seepage risks from subsurface zone (IPCC SR CCS) 21
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Project Boundary and emissions
Emission sources Emissions
CO2 emissions from Energy usage byabove-ground installation
CO2 emissions from fuel and electricity usageCO2 containment failure from above-ground installation
CO2 in Enhanced oil/gas(In case of EOR)
GHG emissions by flareCO2 in enhanced oil/gas
Storage formation CO2 Seepage from storage site
CO2 captureinstallation
CO2 injectioninstallation
Storageformation
CO2 separatinginstallation
CO2 boostinginstallation
dehumidificationinstallation
Pipelines
Emission sources
CO2 rich gas
Project boundary
CO2 captureinstallation
In case of aquifer storage formation,
installations in red dotted line are notincluded.
Supplied CO2
Gas separatinginstallation
Flaringinstallation
CO2 Seepagefrom storage site
CO2 emissions fromenergy usage by
above-groundinstallation
CO2 in Enhancedoil/gas
Without re-injection,installations in greendotted line are not
included.
Flare
CO2 rich oil/gas
Oil
CarbonhydrogenGas
Re-injected CO2
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Detection and Estimation of seepage
1. Monitoring and interpreting the CO2 Saturation
Collecting information on CO2 saturation, such as seismic data,production data or well logging data.
Interpreting CO2 saturation from data obtained.
2. Simulation based on the actual injection Simulating the saturation of CO2 based on actual CO2 injection,
utilizing the three-dimensional model established when characterizing
storage formation.
3. History matching of three-dimensional model Checking whether interpreted CO2 saturation and simulation based on
the actual injection match. (If they dont match) Calibrating three-dimensional model with other
monitored values. The methodology requires procedures and rationale for calibrating
three-dimensional model.
4. Estimating CO2 seepage (If 3. doesnt work) Simulating injection under condition of CO2
seepage with three-dimensional model. Estimating seepage emissions 23
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CO2 saturation monitoring methods
Well logging tools (Reservoir Saturation Tool (RST), Acoustic logging)
Electrical Techniques (Resistivity Contrast Survey)
Seismic methods, ie Two-dimensional seismic surveys, Three/Four-dimensionalseismic,VSP (Vertical Seismic Profiling), crosswell seismic tomography
CO2 saturation logging by RST(with simulated result)
Resistivity Contrast Survey
Monitoring CO2 Saturation
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Various seismic methods
Monitoring CO2 Saturation
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CO2 saturation simulation by three-dimensional earth model
Before injection After injection
The three-dimensional earth model are history-matched by following parameters.
Bottom-hole pressureContinuous measurement by pressure gauge
Fluid production, CO2 concentration in the fluidFluid production data, Gas chromatography
Concentration of CO2 around wells
Well logging tools (Reservoir Saturation Tool (RST),Acoustic logging)
Water/Oil ratio: Electrical Techniques (Resistivity Contrast Survey)
Seismic data: Three/Four-dimensional seismic,VSP (Vertical Seismic Profiling), crosswellseismic tomography
Estimation of seepage emissions
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