The impact of formation water flow on the CO2 storage capacity in the Offshore Gippsland Basin, Australia

The southern Sydney Basin is an ideal natural analogue for CO2 geosequestration because of the widespread CO2 occurrence, extensive data sets available and general knowledge of gas distribution. The CO2 mainly occurs adsorbed in coal, incorporated into carbonate minerals and dissolved in formation water. On this basis, an area of ~900 km2 has been chosen for detailed examination.Gas in the coal seams of this area contain mainly CH4 and CO2, the CO2 content ranging from Calculations indicate that about 78 x 106 tonnes of CO2 are presently stored in coaly intervals in the study area. Assuming a storage capacity of 20 m3/t for these coal seams, the total CO2 storage capacity for the coaly intervals is ~880 x 106 tonnes. Using the study area as an analogue for enhanced coal seam methane production, 175 x 106 tonnes of CO2 could be stored, assuming a 50% CH4 recovery factor and an average CO2 sorption capacity 1.5 times that for CH4.

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GIPPSLAND BASIN GEOSEQUESTRATION: A POTENTIAL SOLUTION FOR THE LATROBE VALLEY BROWN COAL CO2 EMISSIONS

The APPEA Journal ◽

10.1071/aj05024 ◽

2006 ◽

Vol 46 (1) ◽

pp. 413 ◽

Cited By ~ 7

Author(s):

C.M. Gibson-Poole ◽

L. Svendsen ◽

J. Underschultz ◽

M.N. Watson ◽

J. Ennis-King ◽

...

Keyword(s):

Co2 Emissions ◽

Storage Capacity ◽

Transient Flow ◽

Co2 Storage ◽

Oil Field ◽

Stratigraphic Architecture ◽

Gas Trapping ◽

Mineral Trapping ◽

Gippsland Basin ◽

Migration Pathways

Geosequestration of CO2 in the offshore Gippsland Basin is being investigated by the CO2CRC as a possible method for storing the very large volumes of CO2 emissions from the Latrobe Valley area. A storage capacity of about 50 million tonnes of CO2 per year for a 40-year injection period is required, which will necessitate several individual storage sites to be used both sequentially and simultaneously, but timed such that existing hydrocarbon assets are not compromised. Detailed characterisation focussed on the Kingfish Field area as the first site to be potentially used, in the anticipation that this oil field will be depleted within the period 2015–25. The potential injection targets are the interbedded sandstones, shales and coals of the Paleocene-Eocene upper Latrobe Group, regionally sealed by the Lakes Entrance Formation. The research identified several features to the offshore Gippsland Basin that make it particularly favourable for CO2 storage. These include: a complex stratigraphic architecture that provides baffles which slow vertical migration and increase residual gas trapping; non-reactive reservoir units that have high injectivity; a thin, suitably reactive, low permeability marginal reservoir just below the regional seal providing additional mineral trapping; several depleted oil fields that provide storage capacity coupled with a transient flow regime arising from production that enhances containment; and, long migration pathways beneath a competent regional seal. This study has shown that the Gippsland Basin has sufficient capacity to store very large volumes of CO2. It may provide a solution to the problem of substantially reducing greenhouse gas emissions from the use of new coal developments in the Latrobe Valley.

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Impact of faults and compartmentalisation on geological carbon storage estimates in highly faulted basins

The APPEA Journal ◽

10.1071/aj16237 ◽

2017 ◽

Vol 57 (2) ◽

pp. 789

Author(s):

Jorik W. Poesse ◽

Ludovic P. Ricard ◽

Allison Hortle

Keyword(s):

Carbon Storage ◽

Storage Capacity ◽

Co2 Storage ◽

Fault Reactivation ◽

Hydrocarbon Exploration ◽

Co2 Injection ◽

Exploration And Production ◽

Order Of Magnitude ◽

Fault Permeability ◽

The Impact

Faults have extensively been studied for hydrocarbon exploration and production; however, previous studies on fault behaviour for geological carbon storage have focused on sealing capacity or reactivation potential during injection or post-injection phases. Little is known on the impact of faults for estimating storage capacity in highly faulted basins. A geological conceptual model of a representative compartment was designed to identify the key drivers of storage capacity estimates in highly faulted basins. An uncertainty quantification framework was then designed upon this model to address the impact of geological uncertainties such as fault permeability, reservoir injectivity, compartment geometry and closure on the compartment storage capacity. Pressure-limited storage capacity was estimated from numerical simulation of CO2 injection under the constraints of maximum bottom hole pressure and fault reactivation pressure. Interpretation of the simulation results highlights that (1) two injection regimes are observed: borehole- or fault-controlled, (2) storage capacity can vary more than an order of magnitude, (3) fault and reservoir permeability can be regarded as the most influential properties with respect to storage capacity, (4) compartment geometry mainly influences the injection regime controlling the storage capacity and (5) the large sensitivity of storage capacity to the type of enclosure and fault permeability indicates that pressure build-up at the fault is often the deciding factor for CO2 storage capacity.

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Modelling of CO2 Injection in Fluvial Sedimentary Heterogeneous Reservoirs to Assess the Impact of Geological Heterogeneities on CO2 Storage Capacity and Performance

Energy Procedia ◽

10.1016/j.egypro.2013.06.434 ◽

2013 ◽

Vol 37 ◽

pp. 5181-5190 ◽

Cited By ~ 14

Author(s):

Benoît Issautier ◽

Simon Fillacier ◽

Yann Le Gallo ◽

Pascal Audigane ◽

Christophe Chiaberge ◽

...

Keyword(s):

Storage Capacity ◽

Co2 Storage ◽

Co2 Injection ◽

Heterogeneous Reservoirs ◽

And Performance ◽

The Impact

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A data driven model for the impact of IFT and density variations on CO2 storage capacity in geologic formations

Advances in Water Resources ◽

10.1016/j.advwatres.2017.06.015 ◽

2017 ◽

Vol 107 ◽

pp. 83-92 ◽

Cited By ~ 3

Author(s):

Mohammad A. Nomeli ◽

Amir Riaz

Keyword(s):

Storage Capacity ◽

Co2 Storage ◽

Data Driven ◽

The Impact

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The impact of gradational contact at the reservoir-seal interface on geological CO2 storage capacity and security

International Journal of Greenhouse Gas Control ◽

10.1016/j.ijggc.2018.03.007 ◽

2018 ◽

Vol 72 ◽

pp. 1-13 ◽

Cited By ~ 9

Author(s):

Michael U. Onoja ◽

Seyed M. Shariatipour

Keyword(s):

Storage Capacity ◽

Co2 Storage ◽

Geological Co2 Storage ◽

The Impact

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The impact of heterogeneous mixed siliciclastic-carbonate systems on CO2 geological storage

Petroleum Geoscience ◽

10.1144/petgeo2020-086 ◽

2021 ◽

pp. petgeo2020-086

Author(s):

Azadeh Pourmalek ◽

Andrew J. Newell ◽

Seyed M. Shariatipour ◽

Adrian M. Wood

Keyword(s):

Storage Capacity ◽

Co2 Storage ◽

Significant Feature ◽

Carbonate Sediments ◽

Geological Storage ◽

Co2 Geological Storage ◽

Content Type ◽

Storage Security ◽

The Impact ◽

Mixed Systems

Three different outcrops are selected in this study, each representing a shallow marine system with varying heterogeneity provided by siliciclastic-carbonate mixing that may form a small or large stratigraphic trap. The impact of these styles of mixed facies on CO2 storage is relatively poorly known. This study demonstrates the significance of these systems for safe CO2 geological storage, as stratigraphic traps are likely to be a significant feature of many future storage sites. The three 3D models are based on the: 1. Grayburg Formation (US), which displays spatial permeability linked to variations in the mixture of siliciclastic-carbonate sediments; 2. Lorca Basin outcrop (Spain), which demonstrates the interfingering of clastic and carbonate facies; and 3. Bridport Sand Formation outcrop (UK), an example of a layered reservoir, which has thin carbonate-cemented horizons.This study demonstrates that facies interplay and associated sediment heterogeneity have a varying effect on fluid flow, storage capacity and security. In the Grayburg Formation, storage security and capacity are not controlled by heterogeneity alone but influenced mainly by the permeability of each facies (i.e., permeability contrast), the degree of heterogeneity, and the relative permeability characteristic of the system. In the case of the Lorca Basin, heterogeneity through interfingering of the carbonate and clastic facies improved the storage security regardless of their permeability. For the Bridport Sand Formation, the existence of extended sheets of cemented carbonate contributed to storage security but not storage capacity, which depends on the continuity of the sheets. These mixed systems specially minimise the large buoyancy force that act on the top seal and reduce the reliance of the storage security on the overlying caprock. They also increase the contact area between injected CO2 and brine, thereby promoting the CO2 dissolution processes. Overall, mixed systems contribute to the safe storage of CO2.Thematic collection: This article is part of the Geoscience for CO2 storage collection available at: https://www.lyellcollection.org/cc/geoscience-for-co2-storage

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Effect of the number of water alternating CO2 injection cycles on CO2 trapping capacity

The APPEA Journal ◽

10.1071/aj18191 ◽

2019 ◽

Vol 59 (1) ◽

pp. 357 ◽

Cited By ~ 3

Author(s):

Emad A. Al-Khdheeawi ◽

Stephanie Vialle ◽

Ahmed Barifcani ◽

Mohammad Sarmadivaleh ◽

Stefan Iglauer

Keyword(s):

Storage Capacity ◽

Co2 Storage ◽

Storage Period ◽

Co2 Injection ◽

Co2 Leakage ◽

Storage Efficiency ◽

Reservoir Model ◽

Plume Migration ◽

The Impact ◽

Injection Cycle

The CO2 storage capacity is greatly affected by CO2 injection scenario – i.e. water alternating CO2 (WACO2) injection, intermittent injection, and continuous CO2 injection – and WACO2 injection strongly improves the CO2 trapping capacity. However, the impact of the number of WACO2 injection cycles on CO2 trapping capacity is not clearly understood. Thus, we developed a 3D reservoir model to simulate WACO2 injection in deep reservoirs testing different numbers of WACO2 injection cycles (i.e. one, two, and three), and the associated CO2 trapping capacity and CO2 plume migration were predicted. For all different WACO2 injection cycle scenarios, 5000 kton of CO2 and 5000 kton of water were injected at a depth of 2275m and 2125m respectively, during a 10-year injection period. Then, a 100-year CO2 storage period was simulated. Our simulation results clearly showed, after 100 years of storage, that the number of WACO2 cycles affected the vertical CO2 leakage and the capacity of trapped CO2. The results showed that increasing the number of WACO2 cycles decreased the vertical CO2 leakage. Furthermore, a higher number of WACO2 cycles increased residual trapping, and reduced solubility trapping. Thus, the number of WACO2 cycles significantly affected CO2 storage efficiency, and higher numbers of WACO2 cycles improved CO2 storage capacity.

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