scholarly journals Integrated static modelling and dynamic simulation framework for CO2 storage capacity in upper Qishn Clastics, S1A reservoir, Yemen

2021 ◽  
Author(s):  
Ayman Mutahar AlRassas ◽  
Hung Vo Thanh ◽  
Shaoran Ren ◽  
Renyuan Sun ◽  
Nam Le Nguyen Hai ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Large Scale ◽  
Storage Capacity ◽  
Co2 Storage ◽  
Uncertainty Assessment ◽  
Alternative Measure ◽  
Modeling Framework ◽  
Significant Difference ◽  
Static Modelling ◽  
And Storage

Abstract Carbon dioxide (CO2) capture and storage (CCS) is presented as an alternative measure and promising approach to mitigate the large-scale anthropogenic CO2 emission into the atmosphere. In this context, CO2 sequestration into depleted oil reservoirs is a practical approach as it boosts the oil recovery and facilitates the permanent storing of CO2 into the candidate sites. However, the estimation of CO2 storage capacity in subsurfaces is a challenge to kick-start CCS worldwide. Thus, this paper proposes an integrated static and dynamic modeling framework to tackle the challenge of CO2 storage capacity in a clastic reservoir, S1A filed, Masila basin, Yemen. To achieve this work's ultimate goal, the geostatistical modeling was integrated with open-source code (MRST-CO2lab) for reducing the uncertainty assessment of CO2 storage capacity. Also, there is a significant difference between static and dynamic CO2 storage capacity. The static CO2 storage capacity varies from 4.54 to 81.98 million tons, while the dynamic CO2 simulation is estimated from 4.95 to 17.92 million tons. Based on the geological uncertainty assessment of three ranked realizations (P10, P50, P90), our work was found that the upper Qinshn sequence could store 15.64 Million tons without leakage. This result demonstrates that the potential of CO2 utilization is not only in this specific reservoir, but the further CO2 storage for the other clastics reservoirs is promising in the Masila Basin, Yemen.

scholarly journals Quantifying Uncertainty through 3D Geological Modeling for Carbon Capture Utilization and Storage in the Unayzah Formation in Saudi Arabia

2021 ◽  
Author(s):  
Sofia Mantilla Salas ◽  
Miguel Corrales ◽  
Hussein Hoteit ◽  
Abdulkader Alafifi ◽  
Alexandros Tasianas
Keyword(s):  
Saudi Arabia ◽  
Carbon Capture ◽  
Large Scale ◽  
Storage Capacity ◽  
Co2 Storage ◽  
High Energy ◽  
Sequential Gaussian Simulation ◽  
Storage Site ◽  
The Impact ◽  
And Storage

<p>The development of Carbon Capture Utilization and Storage (CCUS) technology paired with existing energy systems will facilitate a successful transition to a carbon-neutral economy that offers efficient and sustainable energy. It will also enable the survival of multiple and vital economic sectors of high-energy industries that possess few other options to decarbonize. Nowadays, just about one-ten-thousandth of the global annual emissions are being captured and geologically-stored, and therefore with today’s emission panorama, CCS large-scale deployment is more pressing than ever. In this study, a 3D model that represents the key reservoir uncertainties for a CCUS pilot was constructed to investigate the feasibility of CO2 storage in the Unayzah Formation in Saudi Arabia. The study site covers the area of the city of Riyadh and the Hawtah and Nuayyim Trends, which contain one of the most prolific petroleum-producing systems in the country. The Unayzah reservoir is highly stratified and it is subdivided into three compartments: the Unayzah C (Ghazal Member), the Unayzah B (Jawb Member), and the Unayzah A (Wudayhi and Tinat Members). This formation was deposited under a variety of environments, such as glaciofluvial, fluvial, eolian, and coastal plain. Facies probability trend maps and well log data were used to generate a facies model that accounted for the architecture, facies distribution, and lateral and vertical heterogeneity of this high complexity reservoir. Porosity and predicted permeability logs were used with Sequential Gaussian Simulation and co-kriging methods to construct the porosity and permeability models. The static model was then used for CO2 injection simulation purposes to understand the impact of the flow conduits, barriers, and baffles in CO2 flow in all dimensions. Similarly, the CO2 simulations allowed us to better understand the CO2 entrapment process and to estimate a more realistic and reliable CO2 storage capacity of the Unayzah reservoir in the area. To test the robustness of the model predictions, geological uncertainty quantification and a sensitivity analysis were run. Parameters such as porosity, permeability, pay thickness, anisotropy, and connectivity were analyzed as well as how various combinations between them affected the CO2 storage capacity, injectivity, and containment. This approach could improve the storage efficiency of CO2 exceeding 60%. The analyzed reservoir was found to be a promising storage site. The proposed workflow and findings of the static and dynamic modeling described in this publication could serve as a guideline methodology to test the feasibility of the imminent upcoming pilots and facilitate the large-scale deployment of this very promising technology.</p>

scholarly journals Enabling Large-Scale Carbon Capture, Utilisation, and Storage (CCUS) Using Offshore Carbon Dioxide (CO2) Infrastructure Developments—A Review

Energies ◽  
2019 ◽  
Vol 12 (10) ◽  
pp. 1945 ◽  
Author(s):  
Lars Ingolf Eide ◽  
Melissa Batum ◽  
Tim Dixon ◽  
Zabia Elamin ◽  
Arne Graue ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Oil Recovery ◽  
Carbon Capture ◽  
Large Scale ◽  
Business Models ◽  
Reservoir Performance ◽  
High Investment ◽  
Co2 Eor ◽  
Carbon Dioxide Co2 ◽  
And Storage

Presently, the only offshore project for enhanced oil recovery using carbon dioxide, known as CO2-EOR, is in Brazil. Several desk studies have been undertaken, without any projects being implemented. The objective of this review is to investigate barriers to the implementation of large-scale offshore CO2-EOR projects, to identify recent technology developments, and to suggest non-technological incentives that may enable implementation. We examine differences between onshore and offshore CO2-EOR, emerging technologies that could enable projects, as well as approaches and regulatory requirements that may help overcome barriers. Our review shows that there are few, if any, technical barriers to offshore CO2-EOR. However, there are many other barriers to the implementation of offshore CO2-EOR, including: High investment and operation costs, uncertainties about reservoir performance, limited access of CO2 supply, lack of business models, and uncertainties about regulations. This review describes recent technology developments that may remove such barriers and concludes with recommendations for overcoming non-technical barriers. The review is based on a report by the Carbon Sequestration Leadership Forum (CSLF).

scholarly journals Maturing global CO2 storage resources on offshore continental margins to achieve 2DS emissions reductions

2019 ◽  
Vol 9 (1) ◽  
Author(s):  
P. S. Ringrose ◽  
T. A. Meckel
Keyword(s):  
Large Scale ◽  
Storage Capacity ◽  
Pore Space ◽  
Co2 Storage ◽  
Emissions Reduction ◽  
Continental Margins ◽  
Emissions Reductions ◽  
Injection Wells ◽  
Reduction Strategies

AbstractMost studies on CO2 emissions reduction strategies that address the ‘two-degree scenario’ (2DS) recognize a significant role for CCS. For CCS to be effective, it must be deployed globally on both existing and emerging energy systems. For nations with large-scale emissions, offshore geologic CO2 storage provides an attractive and efficient long-term strategy. While some nations are already developing CCS projects using offshore CO2 storage resources, most geographic regions have yet to begin. This paper demonstrates the geologic significance of global continental margins for providing broadly-equitable, geographically-relevant, and high-quality CO2 storage resources. We then use principles of pore-space utilization and subsurface pressure constraints together with analogs of historic industry well deployment rates to demonstrate how the required storage capacity can be developed as a function of time and technical maturity to enable the global deployment of offshore storage for facilitating 2DS. Our analysis indicates that 10–14 thousand CO2 injection wells will be needed globally by 2050 to achieve this goal.

CCS AS ONE OF the CO2 EMISSION REDUCTION METHODS

2017 ◽  
pp. 1-8
Author(s):  
Teresa ADAMCZAK-BIAŁY ◽  
Adam WÓJCICKI
Keyword(s):  
United States ◽  
Great Plains ◽  
Oil Recovery ◽  
Carbon Capture ◽  
Large Scale ◽  
Carbon Capture And Storage ◽  
The United States ◽  
Geological Storage ◽  
Co2 Emission Reduction ◽  
And Storage

Information presented in the article allows us to introduce one of the ways of reducing anthropogenic greenhouse gas emissions responsible for the temperature increase and climate change. This is the technology of capture and underground storage of carbon dioxide in geologic structures (Carbon Capture and Storage/Sequestration – CCS). Most of the large-scale CCS projects (i.e. capture and storage of an order of magnitude of 1 million tonnes of CO2 per year) operate in the United States and Canada. Many of them are associated with the use of CO2 captured from the industrial processes for the enhanced oil recovery (EOR). The presented examples of projects are: Boundary Dam Integrated Carbon Capture and Sequestration Demonstration Project (Canada), Great Plains Synfuels and Weyburn-Midale Project (Canada), and Kemper County IGCC Project (United States). CCS projects are crucial for demonstrating the technological readiness and reduce the cost of wider commercial implementation of capture and geological storage of CO2. The status of the projects on geological storage of CO2 in 2015 is 15 large-scale CCS projects operating around the world, and 7 projects in execution.

A Laboratory and Numerical-Simulation Study of Co-Optimizing CO2 Storage and CO2 Enhanced Oil Recovery

SPE Journal ◽  
2015 ◽  
Vol 20 (06) ◽  
pp. 1227-1237 ◽  
Author(s):  
Fatemeh Kamali ◽  
Furqan Hussain ◽  
Yildiray Cinar
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Co2 Storage ◽  
Immiscible Displacement ◽  
Sandstone Sample ◽  
Miscible Displacements ◽  
Gravity Effects ◽  
Optimization Function ◽  
Carbon Dioxide Co2 ◽  
And Storage

Summary This paper presents experimental observations that delineate co-optimization of carbon dioxide (CO2) enhanced oil recovery (EOR) and storage. Pure supercritical CO2 is injected into a homogeneous outcrop sandstone sample saturated with oil and immobile water under various miscibility conditions. A mixture of hexane and decane is used for the oil phase. Experiments are run at 70°C and three different pressures (1,300, 1,700, and 2,100 psi). Each pressure is determined by use of a pressure/volume/temperature simulator to create immiscible, near-miscible, and miscible displacements. Oil recovery, differential pressure, and compositions are recorded during experiments. A co-optimization function for CO2 storage and incremental oil is defined and calculated using the measured data for each experiment. A compositional reservoir simulator is then used to examine gravity effects on displacements and to derive relative permeabilities. Experimental observations demonstrate that almost similar oil recovery is achieved during miscible and near-miscible displacements whereas approximately 18% less recovery is recorded in the immiscible displacement. More heavy component (decane) is recovered in the miscible and near-miscible displacements than in the immiscible displacement. The co-optimization function suggests that the near-miscible displacement yields the highest CO2-storage efficiency and displays the best performance for coupling CO2 EOR and storage. Numerical simulations show that, even on the laboratory scale, there are significant gravity effects in the near-miscible and miscible displacements. It is revealed that the near-miscible and miscible recoveries depend strongly on the endpoint effective CO2 permeability.

scholarly journals Simulating Human Water Regulation: The Development of an Optimal Complexity, Climate-Adaptive Reservoir Management Model for an LSM

2016 ◽  
Vol 17 (3) ◽  
pp. 725-744 ◽  
Author(s):  
Kurt C. Solander ◽  
John T. Reager ◽  
Brian F. Thomas ◽  
Cédric H. David ◽  
James S. Famiglietti
Keyword(s):  
Land Surface ◽  
Large Scale ◽  
Storage Capacity ◽  
Model Performance ◽  
Reservoir Management ◽  
Coefficient Of Determination ◽  
Surface Model ◽  
Essential Components ◽  
Model Equations ◽  
And Storage

Abstract The widespread influence of reservoirs on global rivers makes representations of reservoir outflow and storage essential components of large-scale hydrology and climate simulations across the land surface and atmosphere. Yet, reservoirs have yet to be commonly integrated into earth system models. This deficiency influences model processes such as evaporation and runoff, which are critical for accurate simulations of the coupled climate system. This study describes the development of a generalized reservoir model capable of reproducing realistic reservoir behavior for future integration in a global land surface model (LSM). Equations of increasing complexity relating reservoir inflow, outflow, and storage were tested for 14 California reservoirs that span a range of spatial and climate regimes. Temperature was employed in model equations to modulate seasonal changes in reservoir management behavior and to allow for the evolution of management seasonality as future climate varies. Optimized parameter values for the best-performing model were generalized based on the ratio of winter inflow to storage capacity so a future LSM user can generate reservoirs in any grid location by specifying the given storage capacity. Model performance statistics show good agreement between observed and simulated reservoir storage and outflow for both calibration (mean normalized RMSE = 0.48; mean coefficient of determination = 0.53) and validation reservoirs (mean normalized RMSE = 0.15; mean coefficient of determination = 0.67). The low complexity of model equations that include climate-adaptive operation features combined with robust model performance show promise for simulations of reservoir impacts on hydrology and climate within an LSM.

scholarly journals The application, required investments and operational costs of geological CO2 sequestration: a case study

2019 ◽  
Vol 8 (6) ◽  
pp. e12861023 ◽  
Author(s):  
Pedro Junior Zucatelli ◽  
Ana Paula Meneguelo ◽  
Gisele de Lorena Diniz Chaves ◽  
Gisele de Lorena Diniz Chaves ◽  
Marielce de Cassia Ribeiro Tosta
Keyword(s):  
Carbon Capture ◽  
Large Scale ◽  
Co2 Storage ◽  
Carbon Capture And Storage ◽  
Saline Aquifers ◽  
Natural Systems ◽  
Geological Co2 Sequestration ◽  
And Storage ◽  
Geological Formations

The integrity of natural systems is already at risk because of climate change caused by the intense emissions of greenhouse gases in the atmosphere. The goal of geological carbon sequestration is to capture, transport and store CO2 in appropriate geological formations. In this review, we address the geological environments conducive to the application of CCS projects (Carbon Capture and Storage), the phases that make up these projects, and their associated investment and operating costs. Furthermore it is presented the calculations of the estimated financial profitability of different types of projects in Brazil. Using mathematical models, it can be concluded that the Roncador field presents higher gross revenue when the amount of extra oil that can be retrieved is 9.3% (US$ 48.55 billions approximately in 2018). Additional calculations show that the Paraná saline aquifer has the highest gross revenue (US$ 6.90 trillions in 2018) when compared to the Solimões (US$ 3.76 trillions approximately in 2018) and Santos saline aquifers (US$ 2.21 trillions approximately in 2018) if a CCS project were to be employed. Therefore, the proposed Carbon Capture and Storage method in this study is an important scientific contribution for reliable large-scale CO2 storage in Brazil.

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