Retardation of CO2 Caused by Capillary Pressure Hysteresis: A New CO2 Trapping Mechanism

SPE Journal ◽  
2011 ◽  
Vol 16 (04) ◽  
pp. 784-794 ◽  
Author(s):  
Y.B.. B. Altundas ◽  
T.S.. S. Ramakrishnan ◽  
Nikita Chugunov ◽  
Romain de Loubens
Keyword(s):  
Capillary Pressure ◽  
Saline Water ◽  
Quantitative Measure ◽  
Storage Site ◽  
Self Consistent ◽  
Co2 Plume ◽  
Compare And Contrast ◽  
Acceptability Criteria ◽  
Driving Potential ◽  
Total Dissolution

Summary Containment security of geologically stored CO2 is improved substantially through trapping mechanisms. Therefore, to simulate the potential viability of a storage site, it is necessary to account for immobilization processes. In this paper, we focus on a quantitative measure for the contribution of hysteresis in reducing plume transport, with particular emphasis on capillary-pressure-induced migration retardation. Rocks with large pore-body-to-throat-size ratio, or a low permeability, are the best candidates for this mechanism to be operative. In the present work, a self-consistent relative permeability and capillary pressure hysteresis model is incorporated within a simulator. With this model, it is possible to compare and contrast hysteresis-induced retardation to other mechanisms of trapping. The self-consistent parameterization of all of the transport properties is used to quantify sensitivity compactly. The sensitivity of the CO2-plume shape and the amount of CO2 trapped to the strength of the capillary pressure hysteresis is also described. Simulated results show that the CO2-plume shapes with and without capillary pressure hysteresis are significantly different. As expected, capillary pressure hysteresis retards the buoyant transport of the CO2 plume. Although a portion of the CO2 is connected, and therefore not residual, the plume remains immobile for all practical purposes. Also, because of the decreased driving potential, gravity tonguing below the caprock is reduced in comparison to the case without capillary pressure hysteresis, thus suggesting enhanced storage efficiency. However, the total dissolution of CO2 in saline water is reduced because of the reduced contact area with the brine. Thus, one mechanism of containment is offset by the other. Inclusion of accurate hysteresis models is important for qualifying storage sites constrained by spatial-domain limits. It is anticipated that site-acceptability criteria would change as a result of this study, thereby impacting risk evaluation.

scholarly journals Chemical insights into the electronic structure of Fe(II) porphyrin using FCIQMC, DMRG, and generalized active spaces

2020 ◽  
Author(s):  
Oskar Weser ◽  
Leon Freitag ◽  
Kai Guther ◽  
Ali Alavi ◽  
Giovanni Li Manni
Keyword(s):  
Electron Correlation ◽  
Quantitative Measure ◽  
Model System ◽  
Quintet State ◽  
Consistent Field ◽  
Self Consistent ◽  
Stabilizing Effect ◽  
Self Consistent Field ◽  
Preliminary Version

<div>Stochastic-CASSCF and DMRG procedures have been utilized to quantify the role of the electron correlation mechanisms that in a Fe-porphyrin model system are responsible for the differential stabilization of the triplet over the quintet state. Orbital entanglement diagrams and CI-coefficients of the wave function in a localised orbital basis allow for an effective interpretation of the role of charge-transfer configurations. A preliminary version of the <i>Stochastic Generalized Active Space Self-Consistent Field</i> method has been developed and is here introduced to further assess the pi-backdonation stabilizing effect.</div><div>By the new method excitations between metal and ligand orbitals can selectively be removed from the complete CI expansion. It is demonstrated that these excitations are key to the differential stabilization of the triplet, effectively leading to a quantitative measure of the correlation enhanced pi-backdonation.</div><div><br></div>

3D DAS-VSP Illumination Modeling for CO2 Plume Migration Monitoring in Offshore Sarawak, Malaysia

2021 ◽  
Author(s):  
Pankaj Kumar Tiwari ◽  
Zoann Low ◽  
Parimal Arjun Patil ◽  
Debasis Priyadarshan Das ◽  
Prasanna Chidambaram ◽  
...  
Keyword(s):  
Dynamic Simulation ◽  
Seismic Velocity ◽  
Time Lapse ◽  
Carbonate Reservoir ◽  
Fiber Optic Sensor ◽  
Co2 Injection ◽  
Storage Site ◽  
Plume Migration ◽  
Co2 Plume ◽  
4D Seismic

Abstract Monitoring of CO2 plume migration in a depleted carbonate reservoir is challenging and demand comprehensive and trailblazing monitoring technologies. 4D time-lapse seismic exhibits the migration of CO2 plume within geological storage but in the area affected by gas chimney due to poor signal-to-noise ratio (SNR), uncertainty in identifying and interpretation of CO2 plume gets exaggerated. High resolution 3D vertical seismic profile (VSP) survey using distributed acoustic sensor (DAS) technology fulfil the objective of obtaining the detailed subsurface image which include CO2 plume migration, reservoir architecture, sub-seismic faults and fracture networks as well as the caprock. Integration of quantitative geophysics and dynamic simulation with illumination modelling dignify the capabilities of 3D DAS-VSP for CO2 plume migration monitoring. The storage site has been studied in detailed and an integrated coupled dynamic simulation were performed and results were integrated with seismic forward modeling to demonstrate the CO2 plume migration with in reservoir and its impact on seismic amplitude. 3D VSP illumination modelling was carried out by integrating reservoir and overburden interpretations, acoustic logs and seismic velocity to illustrate the subsurface coverage area at top of reservoir. Several acquisition survey geometries were simulated based on different source carpet size for effective surface source contribution for subsurface illumination and results were analyzed to design the 3D VSP survey for early CO2 plume migration monitoring. The illumination simulation was integrated with dynamic simulation for fullfield CO2 plume migration monitoring with 3D DAS-VSP by incorporating Pseudo wells illumination analysis. Results of integrated coupled dynamic simulation and 4D seismic feasibility were analyzed for selection of best well location to deploy the multi fiber optic sensor system (M-FOSS) technology. Amplitude response of synthetic AVO (amplitude vs offsets) gathers at the top of carbonate reservoir were analyzed for near, mid and far angle stacks with respect to pre-production as well as pre-injection reservoir conditions. Observed promising results of distinguishable 25-30% of CO2 saturation in depleted reservoir from 4D time-lapse seismic envisage the application of 3D DAS-VSP acquisition. The source patch analysis of 3D VSP illumination modelling results indicate that a source carpet of 6km×6km would be cos-effectively sufficient to produce a maximum of approximately 2km in diameter subsurface illumination at the top of the reservoir. The Pseudo wells illumination analysis results show that current planned injection wells would probably able to monitor early CO2 injection but for the fullfield monitoring additional monitoring wells or a hybrid survey of VSP and surface seismic would be required. The integrated modeling approach ensures that 4D Seismic in subsurface CO2 plume monitoring is robust. Monitoring pressure build-ups from 3D DAS-VSP will reduce the associated risks.

Tracking a Deep Co2 Plume: 4d Seismic Imaging at the Aquistore Co2 Storage Site, Saskatchewan, Canada

2019 ◽  
Author(s):  
Don White ◽  
Kyle Harris ◽  
Lisa Roach ◽  
Saeid Cheraghi ◽  
Brian Roberts ◽  
...  
Keyword(s):  
Seismic Imaging ◽  
Co2 Storage ◽  
Storage Site ◽  
Co2 Plume ◽  
4D Seismic

The impact of capillary heterogeneity on CO2 plume migration at the Endurance CCS target site in the UK

2021 ◽  
Author(s):  
Nele Wenck ◽  
Ann Muggeridge ◽  
Julian Barnett ◽  
Samuel Krevor
Keyword(s):  
Water Resources ◽  
Multiphase Flow ◽  
Capillary Pressure ◽  
Small Scale ◽  
Storage Site ◽  
Plume Migration ◽  
Fluid Behaviour ◽  
The Uk ◽  
The Impact ◽  
Capillary Heterogeneity

&lt;p&gt;Characterisation of multiphase flow properties is crucial in predicting large-scale fluid behaviour in the subsurface, for example carbon dixoide (CO&lt;sub&gt;2&lt;/sub&gt;) plume migration at Carbon Capture and Storage (CCS) storage sites. Many of the CO&lt;sub&gt;2&lt;/sub&gt;&amp;#160;storage sites worldwide have displayed unexpected fluid flow behaviour. The CO&lt;sub&gt;2&lt;/sub&gt;&amp;#160;injected underground has migrated in reservoirs away from injection points at much faster rates than had previously been predicted with reservoir simulations [1]. It has emerged that conventional flow simulations are not representing the impact of small-scale heterogeneities in multiphase flow properties, which is a key driver behind these unexpected CO&lt;sub&gt;2&lt;/sub&gt;&amp;#160;migration observations [2]. Heterogeneity in the underlying rock structure can cause large variations in porosity and permeability, which manifest as capillary pressure heterogeneity [3-4]. At the low flow potentials typically encountered during CO&lt;sub&gt;2&lt;/sub&gt;&amp;#160;injection, these heterogeneities can significantly impact fluid flow behaviour, typically observed as large saturation variations within the rock [5-6]. In this work, we have combined experimental and numerical methods to characterise the impact of capillary heterogeneities on plume migration at the Endurance proposed storage site to support the Northern Endurance Partnership (NEP) serving the Zero Carbon Humber and Net Zero Teesside projects in the UK. We built on an approach to characterising capillary heterogeneity at the core scale originating in the work of Krause et al. (2011). The workflow combines core flood experimental data with numerical simulations in a history match, with the experimental 3D saturation distribution as a matching target and the capillary pressure characteristics as a fitting parameter [6]. Through this a 3D digital model of the rock core is built, which incorporates spatial variations in permeability, porosity and capillary heterogeneity. We applied this characterisation effort to reservoir samples from a range of depths within the target interval. Subsequently, these digital core models were used in an upscaling procedure to characterise the impact of small-scale heterogeneities on field scale simulations. The workflow has enabled us to make informed predictions on the observed fluid behaviour at the Endurance storage site. The results emphasize the prevalent impact of small-scale capillary heterogeneities on CO&lt;sub&gt;2&lt;/sub&gt;&amp;#160;plume migration, thus underscore the importance of characterising and incorporating them in reservoir models.&lt;/p&gt;&lt;p&gt;1. Global CCS Institute (2019), Global Status of CCS: 2019.&lt;br&gt;2. Jackson, S. J. and Krevor, S. (2020), &amp;#8216;Small-Scale Capillary Heterogeneity Linked to Rapid Plume Migration During CO2 Storage&amp;#8217;, Geophysical Research Letters 47(18).&lt;br&gt;3. Pini, R., Krevor, S.C. and Benson, S.M., 2012. Capillary pressure and heterogeneity for the CO2/water system in sandstone rocks at reservoir conditions. Advances in Water Resources, 38, pp.48-59.&lt;br&gt;4. Reynolds, C.A., Blunt, M.J. and Krevor, S., 2018. Multiphase flow characteristics of heterogeneous rocks from CO 2 storage reservoirs in the United Kingdom. Water Resources Research, 54(2), pp.729-745.&lt;br&gt;5. Krause, M.H., Perrin, J.C. and Benson, S.M., 2011. Modeling permeability distributions in a sandstone core for history matching coreflood experiments. SPE Journal, 16(04), pp.768-777.&lt;br&gt;6. Jackson, S. J., Agada, S., Reynolds, C. A. and Krevor, S. (2018), &amp;#8216;Characterizing Drainage Multiphase Flow in Heterogeneous Sandstones&amp;#8217;, Water Resources Research 54(4), 3139&amp;#8211;3161.&lt;/p&gt;

scholarly journals Fault hydromechanical characterization and CO2-saturated water injection at the CS-D experiment (Mont Terri Rock Laboratory)

2020 ◽  
Author(s):  
Quinn C. Wenning ◽  
Antonio P. Rinaldi ◽  
Alba Zappone ◽  
Melchior Grab ◽  
Clement Roques ◽  
...  
Keyword(s):  
Fault Zone ◽  
Saline Water ◽  
Water Injection ◽  
Storage Site ◽  
Portable Mass Spectrometer ◽  
Saturated Water ◽  
Constant Head ◽  
Fault Characterization ◽  
Mont Terri ◽  
Mont Terri Rock Laboratory

&lt;p&gt;Understanding potential caprock failure through fault zone leakage is crucial for the safe, long-term containment of a CO&lt;sub&gt;2&lt;/sub&gt; storage site. Thus, the presence of faults in caprocks will greatly affect the site characterization process in terms of the safety assessment. The CS-D experiment at the Mont Terri Lab aims at investigating caprock integrity by determining CO&lt;sub&gt;2&lt;/sub&gt;-rich water mobility in a fault zone. Seven boreholes were drilled in the clay rock, all crosscutting a fault at depths of 17-30 m below the niche floor. The boreholes were fully cored, and the samples analysed in various laboratories. All boreholes were instrumented for monitoring geochemical and geomechanical changes induced by fluid injection for prolonged time, with the goal to better understand mechanisms of CO&lt;sub&gt;2&lt;/sub&gt; leakage in a faulted caprock. We deployed a multi component monitoring setup measuring pressure, axial and 3D deformation, seismic activity and cross-hole electrical resistivity. A borehole was fully dedicated to the monitoring of the injection front, as well as geochemical in-situ measurements and fluid sampling. A portable mass spectrometer for direct measurements of gas has been installed in a dedicated borehole interval. Injection and monitoring activities started in December 2018, with multiple injection tests with saline water at pressures up to 6 MPa, in order to characterize the hydraulic response of the fault. A prolonged injection of CO&lt;sub&gt;2&lt;/sub&gt;-saturated water at constant head pressure started in June 2019 and lasted for about 8 months. In this contribution, we will present the analysis of the data collected during the fault characterization (hydraulic, geophysics, and core analysis) as well as results of the continuous months-long injection. Preliminary interpretation of the monitoring data suggests that a fault does not necessarily form a pathway for the fluid to escape at shallow depth.&lt;/p&gt;

Safeguarding CO2 Storage in a Depleted Offshore Gas Field with Adaptive Approach of Monitoring, Measurement and Verification MMV

2021 ◽  
Author(s):  
Pankaj Kumar Tiwari ◽  
Prasanna Chidambaram ◽  
Ahmad Ismail Azahree ◽  
Debasis Priyadarshan Das ◽  
Parimal Arjun Patil ◽  
...  
Keyword(s):  
Co2 Sequestration ◽  
Co2 Storage ◽  
Storage Site ◽  
Injection Wells ◽  
Plume Front ◽  
Plume Migration ◽  
Co2 Plume ◽  
4D Seismic ◽  
And Storage

Abstract CO2 sequestration is a process for eternity with a possibility of zero-degree failure. One of the key components of the CO2 Sequestration Project is to have a site-specific, risk-based and adaptive Monitoring, Measurement and Verification (MMV) plan. The storage site has been studied thoroughly and is understood to be inherently safe for CO2 sequestration. However, it is incumbent on operator to manage and minimize storage risks. MMV planning is critical along with geological site selection, transportation and storage process. Geological evaluation study of the storage site suggests the containment capacity of identified large depleted gas reservoirs as well as long term conformance due to thick interval. The fault-seal analysis and reservoir integrity study contemplate long-term security of the CO2 storage. An integrated 3D reservoir dynamic simulation model coupled with geomechanical and geochemical models were performed. This helps in understanding storage capacity, trapping mechanisms, reservoir integrity, plume migration path, and injectivity. To demonstrate that CO2 plume migration can be mapped from the seismic, a 4D Seismic feasibility study was carried out using well and fluid data. Gassmann fluid substitution was performed in carbonate reservoir at well, and seismic response of several combination of fluid saturation scenarios on synthetic gathers were analyzed. The CO2 dispersion study, which incorporate integration of subsurface, geomatic and metocean & environment data along with leakage character information, was carried out to understand the potential leakage pathway along existing wells and faults which enable to design a monitoring plan accordingly. The monitoring of wells & reservoir integrity, overburden integrity will be carried out by Fiber Optic System to be installed in injection wells. Significant difference in seismic amplitude observed at the reservoir top during 4D seismic feasibility study for varying CO2 saturation suggests that monitoring of CO2 plume migration from seismic is possible. CO2 plume front with as low as 25% saturation can be discriminated provided seismic data has high signal noise ratio (SNR). 3D DAS-VSP acquisition modeling results show that a subsurface coverage of approximately 3 km2 per well is achievable. Laboratory injectivity studies and three-way coupled modelling simulations established that three injection wells will be required to achieve the target injection rate. As planned injection wells are field centric and storage site area is large, DAS-VSP find limited coverage to monitor the CO2 plume front. Hence, surface seismic acquisition will be an integral component of full field monitoring and time-lapsed evaluations for integrated MMV planning to monitor CO2 plume migration. The integrated MMV planning is designed to ensure that injected CO2 in the reservoir is intact and safely stored for hundreds of years after injection. Field specific MMV technologies for CO2 plume migration with proactive approach were identified after exercising pre-defined screening criteria.

Using Basin Modelling to Understand Injected CO2 Migration and Trapping Mechanisms: A Case Study from the Sleipner CO2 Storage Operation

2021 ◽  
Author(s):  
Geovani Christopher Kaeng ◽  
Kate Evans ◽  
Florence Bebb ◽  
Rebecca Head
Keyword(s):  
Flow Dynamics ◽  
Saline Aquifers ◽  
Storage Site ◽  
Threshold Pressure ◽  
Invasion Percolation ◽  
Hydrocarbon Migration ◽  
Geological Heterogeneity ◽  
Basin Modelling ◽  
Basin Scale ◽  
Co2 Plume

Abstract CO2 migration and trapping in saline aquifers involves the injection of a non-wetting fluid that displaces the in-situ brine, a process that is often termed ‘drainage’ in reservoir flow dynamics. With respect to simulation, however, this process is more typical of regional basin modelling and percolating hydrocarbon migration. In this study, we applied the invasion percolation method commonly used in hydrocarbon migration modelling to the CO2 injection operation at the Sleipner storage site. We applied a CO2 migration model that was simulated using a modified invasion percolation algorithm, based upon the Young-Laplace principle of fluid flow. This algorithm assumes that migration occurs in a state of capillary equilibrium in a flow regime dominated by buoyancy (driving) and capillary (restrictive) forces. Entrapment occurs when rock capillary threshold pressure exceeds fluid buoyancy pressure. Leaking occurs when fluid buoyancy pressure exceeds rock capillary threshold pressure. This is now widely understood to be an accurate description of basin-scale hydrocarbon migration and reservoir filling. The geological and geophysical analysis of the Sleipner CO2 plume anatomy, as observed from the seismic data, suggested that the distribution of CO2 was strongly affected by the geological heterogeneity of the storage formation. In the simulation model, the geological heterogeneity were honored by taking the original resolution of the seismic volume as the base grid. The model was then run at an ultra-fast simulation time in a matter of seconds or minutes per realization, which allowed multiple scenarios to be performed for uncertainty analysis. It was then calibrated to the CO2 plume distribution observed on seismic, and achieved an accurate match. The paper establishes that the physical principle of CO2 flow dynamics follows the Young-Laplace flow physics. It is then argued that this method is most suitable for the regional site screening and characterization, as well as for site-specific injectivity and containment analysis in saline aquifers.

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