scholarly journals Static and Dynamic Estimates of CO2-Storage Capacity in Two Saline Formations in the UK

SPE Journal ◽  
2012 ◽  
Vol 17 (04) ◽  
pp. 1108-1118 ◽  
Author(s):  
M.. Jin ◽  
G.. Pickup ◽  
E.. Mackay ◽  
A.. Todd ◽  
M.. Sohrabi ◽  
...  
Keyword(s):  
Input Data ◽  
Storage Capacity ◽  
Co2 Storage ◽  
Total Pore Volume ◽  
Static Method ◽  
Initial Assessment ◽  
Storage Site ◽  
Aquifer Storage ◽  
The Uk ◽  
Migration Pathways

Summary Estimation of carbon dioxide (CO2)-storage capacity is a key step in the appraisal of CO2-storage sites. Different calculation methods may lead to widely diverging values. The compressibility method is a commonly used static method for estimating storage capacity of saline aquifers: It is simple, is easy to use, and requires a minimum of input data. Alternatively, a numerical reservoir simulation provides a dynamic method that includes Darcy flow calculations. More input data are required for dynamic simulation, and it is more computationally intensive, but it takes into account migration pathways and dissolution effects, so it is generally more accurate and more useful. For example, the CO2-migration plume may be used to identify appropriate monitoring techniques, and the analysis of the trapping mechanism for a certain site will help to optimize well location and the injection plan. Two hypothetical saline-aquifer storage sites in the UK, one in Lincolnshire and the other in the Firth of Forth, were analyzed. The Lincolnshire site has a comparatively simple geology, while the Forth site has a more complex geology. For each site, both static- and dynamic-capacity calculations were performed. In the static method, CO2 was injected until the average pressure reached a critical value. In the migration-monitoring case, CO2 was injected for 15 years, and was followed by a closure period lasting thousands of years. The fraction of dissolved CO2 and the fraction immobilized by pore-scale trapping were calculated. The results of both geological systems show that the migration of CO2 is strongly influenced by the local heterogeneity. The calculated storage efficiency for the Lincolnshire site varied between 0.34% and 0.65% of the total pore-volume, depending on whether the system boundaries were considered open or closed. Simulation of the deeper, more complex Forth geological system gave storage capacities as high as 1.05%. This work was part of the CO2-Aquifer-Storage Site Evaluation and Monitoring (CASSEM) integrated study to derive methodologies for assessment of CO2 storage in saline formations. Although static estimates are useful for initial assessment when fewer data are available, we demonstrate the value of performing dynamic storage calculations and the opportunities to identify mechanisms for optimizing the storage capacity.

GEOLOGICAL STORAGE OF CARBON DIOXIDE: MODELLING THE EARLY CRETACEOUS SUCCESSION IN THE BARROW SUB-BASIN, NORTHWEST AUSTRALIA

2004 ◽  
Vol 44 (1) ◽  
pp. 653 ◽  
Author(s):  
C.M. Gibson-Poole ◽  
J.E. Streit ◽  
S.C. Lang ◽  
A.L. Hennig ◽  
C.J. Otto
Keyword(s):  
Storage Capacity ◽  
Flow Direction ◽  
Co2 Storage ◽  
Column Height ◽  
Co2 Injection ◽  
Technical Solution ◽  
Exit Point ◽  
Geological Storage ◽  
Migration Pathways ◽  
Northwest Australia

Potential sites for geological storage of CO2 require detailed assessment of storage capacity, containment potential and migration pathways. A possible candidate is the Flag Sandstone of the Barrow Sub-basin, northwest Australia, sealed by the Muderong Shale. The Flag Sandstone consists of a series of stacked, amalgamated, basin floor fan lobes with good lateral interconnectivity. The main reservoir sandstones have high reservoir quality with an average porosity of 21% and an average permeability of about 1,250 mD. The Muderong Shale has excellent seal capacity, with the potential to withhold an average CO2 column height of 750 m. Other containment issues were addressed by in situ stress and fault stability analysis. An average orientation of 095°N for the maximum horizontal stress was estimated. The stress regime is strike-slip at the likely injection depth (below 1,800 m). Most of the major faults in the study area have east-northeast to northeast trends and failure plots indicate that some of these faults may be reactivated if CO2 injection pressures are not monitored closely. Where average fault dips are known, maximum sustainable formation pressures were estimated to be less than 27 MPa at 2 km depth. Hydrodynamic modelling indicated that the pre-production regional formation water flow direction was from the sub-basin margins towards the centre, with an exit point to the southwest. However, this flow direction and rate have been altered by a hydraulic low in the eastern part of the sub-basin due to hydrocarbon production. The integrated site analysis indicates a potential CO2 storage capacity in the order of thousands of Mtonnes. Such capacity for geological storage could provide a technical solution for reducing greenhouse gas emissions.

scholarly journals The Endurance CO2 storage site, Blocks 42/25 and 43/21, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 163-171 ◽  
Author(s):  
Jon G. Gluyas ◽  
Usman Bagudu
Keyword(s):  
Carbon Capture ◽  
Co2 Storage ◽  
Carbon Capture And Storage ◽  
Lower Triassic ◽  
Injection Rate ◽  
Government Support ◽  
Storage Site ◽  
Sandstone Formation ◽  
The Uk ◽  
And Storage

AbstractThe Endurance, four-way, dip-closed structure in UK Blocks 42/25 and 43/21 occurs over a salt swell diapir and within Triassic and younger strata. The Lower Triassic Bunter Sandstone Formation reservoir within the structure was tested twice for natural gas (in 1970 and 1990) but both wells were dry. The reservoir is both thick and high quality and, as such, an excellent candidate site for subsurface CO2 storage.In 2013 a consortium led by National Grid Carbon drilled an appraisal well on the structure and undertook an injection test ahead of a planned development of Endurance as the first bespoke storage site on the UK Continental Shelf with an expected injection rate of 2.68 × 106 t of dense phase CO2 each year for 20 years. The site was not developed following the UK Government's removal of financial support for carbon capture and storage (CCS) demonstration projects, but it is hoped with the recent March 2020 Budget that government support for CCS may now be back on track.

scholarly journals Static and Dynamic Estimates of CO2 Storage Capacity in Two Saline Formations in the UK

2010 ◽  
Author(s):  
Min Jin ◽  
Gillian E. Pickup ◽  
Eric James Mackay ◽  
Adrian Christopher Todd ◽  
Alison Monaghan ◽  
...  
Keyword(s):  
Storage Capacity ◽  
Co2 Storage ◽  
The Uk

Integrated Coupled Modelling Study to Assess CO2 Sequestration Potential in a Depleted Gas Field

2021 ◽  
Author(s):  
Ahmad Ismail Azahree ◽  
Farhana Jaafar Azuddin ◽  
Siti Syareena Mohd Ali ◽  
Muhammad Hamzi Yakup ◽  
Mohd Azlan Mustafa ◽  
...  
Keyword(s):  
Storage Capacity ◽  
Co2 Storage ◽  
Coupled Model ◽  
Co2 Injection ◽  
Storage Site ◽  
Coupled Modeling ◽  
Reservoir Properties ◽  
Gas Field ◽  
Sequestration Potential ◽  
Injection Phase

Abstract A depleted gas field is selected as CO2 storage site for future high CO2 content gas field development in Malaysia. The reservoir selected is a carbonate buildup of middle to late Miocene age. This paper describes an integrated modeling approach to evaluate CO2 sequestration potential in depleted carbonate gas reservoir. Integrated dynamic-geochemical and dynamic-geomechanics coupled modeling is required to properly address the risks and uncertainties such as, effect of compaction and subsidence during post-production and injection. The main subsurface uncertainties for assessing the CO2 storage potential are (i) CO2 storage capacity due to higher abandonment pressure (ii) CO2 containment due to geomechanical risks (iii) change in reservoir properties due to reaction of reservoir rock with injected CO2. These uncertainties have been addressed by first building the compositional dynamic model adequately history matched to the production data, and then coupling with geomechanical model and geochemical module during the CO2 injection phase. This is to further study on the trapping mechanisms, caprock integrity, compaction-subsidence implication towards maximum storage capacity and injectivity. The initial standalone dynamic modeling poses few challenges to match the water production in the field due to presence of karsts, extent of a baffle zone between the aquifer and producing zones and uncertainty in the aquifer volume. The overall depletion should be matched, since the field abandonment pressure impacts the CO2 injectivity and storage capacity. A reasonably history matched coupled dynamic-geomechanical model is used as base case for simulating CO2 injection. The dynamic-geomechanical coupling is done with 8 stress steps based on critical pressure changes throughout production and CO2 injection phase. Overburden and reservoir properties has been mapped in Geomechanical grid and was run using two difference constitutive model; Mohr's Coulomb and Modified Cam Clay respectively. The results are then calibrated with real subsidence measurement at platform location. This coupled model has been used to predict the maximum CO2 injection rate of 100 MMscf/d/well and a storage capacity of 1.34 Tscf. The model allows to best design the injection program in terms of well location, target injection zone and surface facilities design. This coupled modeling study is used to mature the field as a viable storage site. The established workflow starting from static model to coupled model to forecasting can be replicated in other similar projects to ensure the subsurface robustness, reduce uncertainty and risk mitigation of the field for CO2 storage site.

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

2006 ◽  
Vol 46 (1) ◽  
pp. 413 ◽  
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.

3D modelling and capacity estimation of potential targets for CO2 storage in the Adriatic Sea, Italy

2021 ◽  
pp. petgeo2020-117
Author(s):  
Giampaolo Proietti ◽  
Marko Cvetković ◽  
Bruno Saftić ◽  
Alessia Conti ◽  
Valentina Romano ◽  
...  
Keyword(s):  
Carbon Dioxide Emissions ◽  
Storage Capacity ◽  
Adriatic Sea ◽  
Co2 Storage ◽  
Dynamic Modelling ◽  
3D Modelling ◽  
Saline Aquifers ◽  
Storage Site ◽  
Geological Storage ◽  
Capacity Estimation

One of the most innovative and effective technologies developed in recent decades for reducing carbon dioxide emissions to the atmosphere is CCS (Carbon Capture & Storage). It consists of capture, transport and injection of CO2 produced by energy production plants or other industries. The injection takes place in deep geological formations with the suitable geometrical and petrophysical characteristics to permanently trap CO2 in the subsurface, which is called geological storage. In the development process of a potential geological storage site, correct capacity estimation of the injectable volumes of CO2 is one of the most important aspects. There are various approaches to estimate CO2 storage capacities for potential traps, including geometrical equations, dynamic modelling, numerical modelling, and 3D modelling. In this work, generation of three-dimensional petrophysical models and equations for calculation of the storage volumesare used to estimate the effective storage capacity of four potential saline aquifers in the Adriatic Sea offshore. The results show how different saline aquifers, with different lithologies at favourable depths, can host a fair amount of CO2, that will imply a further and more detailed feasibility studies for each of these structures. A detailed analysis is carried out for each saline aquifer identified, varying the parameters of each structure identified, and adapting them for a realistic estimate of potential geological storage capacity.Thematic collection: This article is part of the Geoscience for CO2 storage collection available at: https://www.lyellcollection.org/cc/geoscience-for-co2-storage

ASCAPE: A Flexible and Efficient Analytical Tool to Evaluate Aquifer Storage Capacity for CO2 Sequestration

2021 ◽  
Author(s):  
Fabrizio Freni ◽  
Vincenzo Napolitano ◽  
Silvia Mancini ◽  
Roberto Buscaglia
Keyword(s):  
Co2 Sequestration ◽  
Storage Capacity ◽  
Water Pressure ◽  
Co2 Storage ◽  
Economic Feasibility ◽  
Preliminary Evaluation ◽  
Water Production ◽  
Co2 Solubility ◽  
Aquifer Storage ◽  
Pressure Increment

Abstract In recent years, carbon neutrality has emerged as an important social and political focus globally, where carbon sequestration plays a key role. The present work is aimed at introducing ASCAPE (Aquifer Storage CAPacity Evaluation tool), a fast and flexible tool useful in case of CO2 aquifer sequestration to preliminarily evaluate the required storage capacity as a function of the maximum allowable pressure increment. ASCAPE is based on the volumetric method included in SPE "Guidelines for Applications of the CO2 Storage Resources Management System" (SPE, 2020) for aquifer sequestration. The analytical formula was integrated to include additional physical phenomena as CO2 solubility in water, pressure control through water production, effect of gas pools connected to aquifer. The tool, implemented in Excel/VBA environment, allows to easily obtain a theoretical Pressure increment vs. Aquifer Volume curve useful to estimate the required aquifer volume to store a given quantity of CO2. ASCAPE results were validated comparing to a simplified 3D model simulated by a compositional commercial dynamic simulator. The validation showed a very good alignment with the 3D dynamic simulation results under several conditions. Many tests were performed with and without the CO2 solubility model, demonstrating that this phenomenon acts as pressure increment reducer. The original volumetric model can be therefore considered slightly conservative, since it neglects this physical contribution, which allowed to improve the reliability of the proposed analytical model. The proposed methodology is a general-purpose application being not related to a specified candidate and, therefore, it can be tailored on the specific scenario to be evaluated. ASCAPE was developed for preliminary screening of CO2 sequestration concepts in greenfield development areas, where the absence of brown or exhausted fields makes the storage in aquifer the only viable solution. Different aquifers were compared under certain assumptions of carbon to be stored with and without water production, allowing a preliminary evaluation that will be used to rank the concepts in terms of technical/economic feasibility.

CO2 storage capacity estimation for a deep saline formation by static reservoir modelling: the Cretaceous Paaratte Formation, offshore Otway Basin, Victoria

2015 ◽  
Vol 55 (1) ◽  
pp. 283
Author(s):  
Angie Qu ◽  
Mark Bunch ◽  
John Kaldi
Keyword(s):  
Storage Capacity ◽  
Volume Fraction ◽  
Co2 Storage ◽  
Total Pore Volume ◽  
Effective Porosity ◽  
Seismic Survey ◽  
Equivalent Model ◽  
3D Seismic ◽  
Survey Area ◽  
Net To Gross

This study used stochastic simulation to estimate the CO2 storage capacity of the Cretaceous Paaratte Formation within the Casino 3D seismic survey area of the offshore Otway Basin, Victoria. Besides interpretation results from primary hard data (well data), relative acoustic impedance was used as secondary soft (proxy) data to model the distribution of the volume fraction of shale (V-Shale). The V-Shale model provided an equivalent model of lithofacies for the clastic reservoir. V-Shale correlated well with the net-to-gross and effective porosity parameters in well log interpretation results. Collocated co-kriging was then used to model the distributions of net-to-gross and effective porosity from well profiles by stochastic co-simulation processes. Using the total pore volume (TPV) obtained from this 3D modelling and storage efficiency factors defined by US DOE-NETL (2012), the potential CO2 storage capacity of the Paaratte reservoir is estimated to be between 11.94 million tonnes (P90) and 128.75 million tonnes (P10) within the geographic footprint of the Casino 3D seismic survey area. The expected TPV storage capacity (P50 confidence interval) is 46.82 million tonnes.

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