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This presentation was given as part of the CCS Ready workshop which was held in association with the 6th Asia Clean Energy Forum (20 – 24 June, Manila)The workshop discussed the range of measures and best practices that can be implemented to prompt the design, permitting and construction of CCS projects when designing or building a new fossil fuelled energy or industrial plant. The workshop hosted participants of the Asian Development Banks’ Regional Technical Assistance Program who updated the group on the outcomes of their individual projects.This presentation provides an update on the current project being undertaken under the Asian Development Bank’s Regional Technical Assistance Program which aims to conduct an analysis of the potential for CCS, culminating in a road map for a CCS demonstration project in Indonesia.
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R & D Centre for Oil and Gas Technology
“LEMIGAS”
Manila, 23 June 2011
Carbon Capture and Storage: Prospect & Development in Indonesia
Page 2
Outline
Background
Indonesia’s Pathway in CCS
Prospect of CCS Deployment
CCS Development in Indonesia
Main Issues and Challenges on CCS Deployment in
Indonesia
Basin Assessment and CO2 Storage Capacity Estimation
in Depleted Reservoirs
Selected Area for ADB Technical Assistance for CCS
Conclusions
Page 3
Background
• GOI’s non-binding commitment to reduce
country emissions to 26% in 2020
• Current efforts are considered still
insufficient to achieve CO2 emissions
abatement target in 2020
• energy mix improvements
• the switch to less-carbon intensive fuels
• renewable resources deployment
• It is imperative for Indonesia to
investigate options for CCS Energy mix improvement for 2025 is still dominated by fossil fuel
As a result of objective function of Energy mix improvement :
The energy sector can achieve 950 Mt CO2reduction in 2025 from 1150 Mt in BaU
Page 4
1. Preliminary studies on CCS-EOR in East Kalimantan & South
Sumatra (2003 – 2005)
2. Joint study on CCS potential with industries:
• Sojitz & Mitsubishi (2005); Total Indonesie (2007); Shell (2008);
and KIGAM (2010)
• MoU with METI-Japan CCS (2010)
3. Became a founding member of Global CCS Institute
(GCCSI) led by Australia (April 2009)
4. Joint Study with UK Government (November, 2009)
5. Other Cooperation:
• IEA - CCS Roadmap and Establishing of National Regulatory
Framework
Indonesia’s Pathway in CCS
Page 5
CCS-EOR in East Kalimantan
1. 10 reservoirs are suitable for CO2-EOR
2. Screening Reservoirs from MMP
• MMP > current reservoir pressure
• 3 reservoirs above 0.8 psi/ft were eliminated (above pf)
3. Rule of Thumb Method:
• Potential Oil Recoveries of 3.6 – 7.2 MMSTB
• Sequestration volumes of 0.5 – 2.1 Million tons
4. The Results of Laboratory Study:• The result of CO2 injection at 3000 psig reveals that the recovery factor
was 93.3% OOIP after 1.2 PV CO2 injected.
5. The Simulation Results:• Continues CO2 injection
− Potential oil recoveries of 2.6 – 3.3 MMSTB− Sequestration volumes of 4.7 – 4.9 Million tons
• 1 : 1 WAG− Potential oil recoveries of 2.4 MMSTB− Sequestration volumes of 2.2 Million ton
Page 6
A first comprehensive study to identify CCS potential deployment in Indonesia
Title: Understanding Carbon Capture and Storage Potential In Indonesia
Study Objective: To develop an understanding of the requirements associated with deploying CCS in Indonesia by addressing technical, commercial and regulatory aspects of CCS deployment.
CCS Study Working Group: Ministry of Energy and Mineral Resources (BALITBANG/LEMIGAS) , State Ministry of Environment, Shell, PLN, World Energy Council, and supported by UK Embassy in Jakarta
Status: Completed November 2009. Full report available at http://www.worldenergy.org/news__events/news/2746.asp
Joint Study with UK Government
Page 7
Power Plant
Legend:
Storage Location
Pipeline
Note: Unscaled Map
Gas Processing Plant
GUU
U
Muara Tawar 2,3,4
Combined Cycle Power Plant
3 x 750 MW
Emissions Projection up to
2018: 26.6 MtCO2
Indramayu
Steam Coal Power Plant
2 x 1000 MW
Emissions Projection up to
2018: 65.8 MtCO2
Jawa Sea Offshore
South Sumatera Onshore
East Kalimantan Onshore
Bangko Tengah
Steam Coal Power Plant
4 x 600 MW
Emissions Projection up to
2018: 11.5 MtCO2
Subang
Gas Processing Plant
Emissions Projection up to
2018: 6.2 MtCO2
Muara Jawa
Steam Coal Power Plant
2 x 100 MW
Emissions Projection up to
2018: 10.6 MtCO2
60 km
60 km
320 km
35 km300 km
15 km
129.7 km
Power Plant
Legend:
Storage Location
Pipeline
Note: Unscaled Map
Gas Processing Plant
Power Plant
Legend:
Storage Location
Pipeline
Note: Unscaled Map
Gas Processing Plant
GUU
GUU
U
Muara Tawar 2,3,4
Combined Cycle Power Plant
3 x 750 MW
Emissions Projection up to
2018: 26.6 MtCO2
Indramayu
Steam Coal Power Plant
2 x 1000 MW
Emissions Projection up to
2018: 65.8 MtCO2
Jawa Sea Offshore
South Sumatera Onshore
East Kalimantan Onshore
Bangko Tengah
Steam Coal Power Plant
4 x 600 MW
Emissions Projection up to
2018: 11.5 MtCO2
Subang
Gas Processing Plant
Emissions Projection up to
2018: 6.2 MtCO2
Muara Jawa
Steam Coal Power Plant
2 x 100 MW
Emissions Projection up to
2018: 10.6 MtCO2
60 km
60 km
320 km
35 km300 km
15 km
129.7 km
Possible CCS Scheme in Indonesia (Power Plants)
Page 8 Page │ 8
Existing CO2 Capture in Indonesia
Other PERTAMINA’S Planned CO2 Removal Plant
East Natuna: 2.4 BCSFD CO2
Cepu: 72.5 MMSCFD CO2
Bontang LNG Plant: 30.000 tD CO2
0 50 100 150 200
Subang
Cilamaya
Merbau
Gundih
MMSCFD
Full Capacity
Operational Capacity
Source: Modified from PERTAMINA
LEMIGAS
CO2 Production From
Bontang Area : +
30.000 T/D
Page 9
CCS Development in Indonesia
2006 2007 2008 2009 2010 2011
CO2 Sequestration
on Geological
Storage
CO2Sequestration
on Saline
Aquifer
Laboratory
and
Reservoir
Simulation
Study of
CO2Injection in
Depleted
Reservoir
Worksheet
Screening CO2Sequestration
Potential
Basin
Assessment
and CO2Storage
Capacity
Estimation in
Depleted
Reservoirs
Merbau Field
Demo Project
Proposal
. . . . . .
Page 10
CCS Development in Indonesia
2010 2011 2012 2013 2014
I. CO2 EMISSION FROM ENERGY SECTOR1.1 CO2 Emission from Energy Sector
1.2 Impact of Energy Effieciecy and Renewable Energy
II. CARBON TRADE
2.1 Carbon Trade Mechanism
2.2 CCS as CDM Activity
III. LEGAL AND REGULATORY FRAMEWORK ON CCS3.1 Existing Legal and Regulatory Framework from Developed Countries
3.2 Establish National Regulatory Framework
IV. CCS Potential on Geological Formation4.1 CO2 Emission Source
4.2 Capture and Transportation Technology
4.3 CO2 Storage on Depleted Oil and Gas Reservoirs
4.4 CO2 Stirage on Deep Saline Aquifers and Coalbed Methane
4.5 CCS Cost Unit
4.6 Risk Assessment
ROADMAP of CCS R&DYear 2010-2014
NO Activity Year
Page 11
• New build Coal-fired power plants as a target from large point
sources of CO2 emissions
• The utilization of CO2 in petroleum industry particularly for
enhanced oil recovery (EOR)
• Enabling development of highly contaminated gas fields e.g.
Natuna D alpha
• In line with Government non-binding commitment to reduce
country emissions to 26% in 2020.
Prospect of CCS Deployment
Page 12
• No public awareness of CCS and lack of technical capacity
• CCS costs must be reduced
• No Legal and Regulatory Frameworks
• Need accelerating investment on R&D
• Demonstration projects are needed in developing countries
funded by international sources
Main Issues and Challenges on CCS Deployment
Page 13 Page │ 13
CRITERIA
Increasing CO2 Storage Potential
CLASSES
1 2 3 4 5
On/Off Shore Deep Offshore Shallow Offshore Onshore
GeothermalWarm
(>400C/km)Moderate
Cold
(<300C/km)
Maturity Unexploration Exploration Development Production Basin
Fault Intensity Extensive
Faulted and
fracture
Moderately Faulted
and fractureLimited Faulting and fracturing
Tectonic Setting For Arc Back Arc Platform Deltaic Rift Vally
Depth (meter)Shallow
(<1,500m)
Intermediate
(1,500-3,500 m)
Deep
(>3,500 m)
Size Small Medium Large Giant
Hydrocarbon
PotentialNone Small Medium Large Giant
Accessibility Inaccessible Difficult AcceptableEasy
Infrastructure None Minor Moderate Extensive
Developing Screening Criteria for Specific Indonesian Sedimentary BasinsModified from Bachu, 2003 and CO2CRC, 2009
LEMIGAS
Basin Assessment (Site Selection)
Page 14 Page │ 14
Key assumptions
The Volume previously occupied by, by
and large the produced hydrocarbons
becomes available for CO2 storage
Reservoirs are not flooded (Secondary
& tertiary recovery)
Reservoirs are not in hydrodynamic
contact with an aquifer
Density was calculated using EOS
Span & Wagner
Np/Ult ratio ≥ 55%
BSeffURMCO rCO 22
Where:
MCO2 = CO2 storage capacity of the aquifer
CO2r = CO2 Density at P & T Reservoir
UR = Ultimate Recovery
Seff = Storage Efficiency Factor
B = Formation Volume Factor
Source: Bachu., et al, 2007 & Poulsen., et al. 2009
S i m p l i f i e d C a r b o n S e q ues t ra t i o n
Leadership Forum (CSLF) Methodology
LEMIGAS
Storage Capacity Estimation in Depleted Oil and Gas Reservoirs
Page 15 Page │ 15
Selected Area for ADB Technical Assistance for CCS
South Sumatera
Specific Area for Demonstration Project
Merbau Gas Field
Merbau CO2 Removal Plant
Rationale
• Large presence of the industrial and power sector in South Sumatera Large potential and
various CO2 sinks (depleted hydrocarbon reservoirs, and coal seams)
• South Sumatera has low density population
• Existing infrastructure
• Stable geological formations from seismic and tectonic activity
• South Sumatera sedimentary basin has high suitability for CO2 storage
LEMIGAS
Page 16 Page │ 16
Identified Large Stationary CO2 Sources in South Sumatera
Power Plant
Coal Mining
Paper Plant
Cement Plant
Refinery
Gas Processing
Plant
Fertilizer Plant
Oil and Gas
Industry
LEMIGAS
Page 17 Page │ 17
Methodology for Calculating CO2 Emissions
2006 IPCC Guidelines for National Greenhouse Gas Inventories
■ Fuel Combustion:
■ Industry :
Shell Guidance 2006
■ Fuel Combustion :
API Compendium 2009
■ Flare:
12
442 ContentCarbonGasNaturalCO
12
442 EFQCO
12
442
CarbonMassMollar
MassMollarCarbonUsedFuelCO
12
44%2 mixtureCWTUsedFuelCO
LEMIGAS
Page 18 Page │ 18
Candidate Field for CO2 Storage: Merbau Field
Owner : PERTAMINA
Discovery : 1975
Delineation : 1980
Total Well : ~17 Wells
Main Reservoir : Baturaja Formation (BRF)
Res. Depth : (1650 – 2100) m TVD
Aver Res. Thick : 70m
Average Porosity : 11% (5 – 15)%
Average Sw : 28% (10 – 35)%
Average Pressure : (2750 – 2850) psi at 1800 m tvd
Average Temperature : (260 – 270)0 F
OGIP (BSCF) : 353.577 (Status 2005)
RESERVE (BSCF) : 282.861
Current Production : 300 MMSCFD
LEMIGAS
Page 19
• Deployment of CCS in Indonesia is aligned with national
energy policy and GoI’s commitment to reduce 26% country
emission.
• This pre-feasibility analysis for a demonstration CCS project
will culminate in the development of a roadmap for CCS
demonstration.
• CCS in conjunction with CO2-EOR will be the main highlight
in this project
• Other CCS key elements such as legal and regulatory
framework and socio-economic will also be assessed.
Conclusions
Page 20
Thank You
Agency of R&D for Energy and Mineral Resources
R & D C e n t r e f o r O i l a n d G a s Te c h n o l o g y
Republic of Indonesia LEMIGAS
