scholarly journals Technical and Economic Evaluation of CO2 Capture and Reinjection Process in the CO2 EOR and Storage Project of Xinjiang Oilfield

Energies ◽  
2021 ◽  
Vol 14 (16) ◽  
pp. 5076
Author(s):  
Liang Zhang ◽  
Songhe Geng ◽  
Linchao Yang ◽  
Yongmao Hao ◽  
Hongbin Yang ◽  
...  
Keyword(s):  
Co2 Capture ◽  
Membrane Separation ◽  
Co2 Storage ◽  
Pilot Project ◽  
Gas Production ◽  
Co2 Emission Reduction ◽  
Production Scale ◽  
Co2 Eor ◽  
Pressure Swing ◽  
And Storage

CO2 capture and reinjection process (CCRP) can reduce the used CO2 amount and improve the CO2 storage efficiency in CO2 EOR projects. To select the best CCRP is an important aspect. Based on the involved equipment units of the CCRP, a novel techno-economic model of CCRP for produced gas in CO2 EOR and storage project was established. Five kinds of CO2 capture processes are covered, including the chemical absorption using amine solution (MDEA), pressure swing adsorption (PSA), low-temperature fractionation (LTF), membrane separation (MS), and direct reinjection mixed with purchased CO2 (DRM). The evaluation indicators of CCRP such as the cost, energy consumption, and CO2 capture efficiency and purity can be calculated. Taking the pilot project of CO2 EOR and storage in XinJiang oilfield China as an example, a sensitivity evaluation of CCRP was conducted based on the assumed gas production scale and the predicted yearly gas production. Finally, the DRM process was selected as the main CCRP associated with the PSA process as an assistant option. The established model of CCRP can be a useful tool to optimize the CO2 recycling process and assess the CO2 emission reduction performance of the CCUS project.

Active CO2 Reservoir Management for CO2 Capture, Utilization, and Storage: An Approach to Improve CO2 Storage Capacity and to Reduce Risk

2012 ◽  
Author(s):  
Thomas A. Buscheck ◽  
Samuel Julius Friedmann ◽  
Yunwei Sun ◽  
Mingjie Chen ◽  
Yue Hao ◽  
...  
Keyword(s):  
Co2 Capture ◽  
Storage Capacity ◽  
Co2 Storage ◽  
Reservoir Management ◽  
Reduce Risk ◽  
And Storage

scholarly journals CO2 EOR with in-situ CO2 capture, a Neuquina basin oxycombustion case study

2020 ◽  
Vol 10 (2) ◽  
pp. 39-47
Author(s):  
Gonzalo Gallo ◽  
Raul Puliti ◽  
Rodolfo Torres ◽  
Eleonora Erdmann
Keyword(s):  
Co2 Capture ◽  
Low Cost ◽  
Gas Production ◽  
Co2 Injection ◽  
Discount Rates ◽  
Sweep Efficiency ◽  
High Co2 ◽  
Co2 Eor ◽  
Production Response

Given the growing interest in the capture and utilization of CO2 in recent years, several technologies have emerged that seek to generate CO2 in-situ at a low cost. There are promising developments, which allow capturing CO2 with sufficient purity to be used for EOR. Oxycombustion has high potential in the region as this technology benefits from gas production with a high CO2 content, which significantly reduces the cost of capture. Additionally, carbon dioxide separation techniques such as air capture, fuel cells, amines, and membranes are considered. Argentina has several fields, which produce gas with high CO2 content benefiting Oxycombustion economics.   The paradigm change not only occurs in technology but also in the implementation schemes. The vast majority of the development of CO2 EOR are carried out in the USA with very low CO2 costs and high availability. When considering the costs of CO2 per ton (metric ton) that could be obtained in Argentina, and financial variables such as high discount rates, it is clear that the injection model has to be optimized for these conditions. In order to optimize profitability, it is crucial to improve the payout time and the usage of CO2. In one hand, smaller slugs lead to better CO2 utilization rates (oil produced/CO2 injected) while larger slugs lead to faster oil production response. We observed that due to the high discount rates in the area, faster production response has a higher economic impact that sweep efficiency or breakthrough times. It seems to be better to sacrifice overall recovery factor in order to extract oil as soon as possible. Optimal injection schemes where found for different scenarios. Additionally, starting the project early is a key parameter for both technical and economic success.    Another key technical difference is that the available CO2 volume for injection is constant due to the nature of these capture techniques. Unlike purchasing CO2 from a pipeline, where gas can be purchased as needed, Oxycombustion (or other capture methods) produces a continuous stream limiting injection flexibility. All produced CO2 must be injected as it is being produced and, until production gas reaches a CO2 content high enough to assure MMP, CO2 injection stream cannot exceed the maximum CO2 capture capacity. CO2 EOR has significant advantages over Chemical EOR due to its significant recovery factors and early response. Additionally, this technology applies to reservoirs of low permeability and / or high temperature where the polymer can have problems of injectivity or degradation. 

Joint Optimization of Well Completions and Controls for CO2 Use and Storage

2021 ◽  
Vol 73 (06) ◽  
pp. 67-68
Author(s):  
Chris Carpenter
Keyword(s):  
Oil Recovery ◽  
Optimization Problem ◽  
Co2 Storage ◽  
Oil Production ◽  
Joint Optimization ◽  
Optimization Approach ◽  
Well Control ◽  
Co2 Eor ◽  
Well Completions ◽  
And Storage

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 200316, “Joint Optimization of Well Completions and Controls for CO2 Enhanced Oil Recovery and Storage,” by Bailian Chen, SPE, and Rajesh Pawar, Los Alamos National Laboratory, prepared for the 2020 SPE Improved Oil Recovery Conference, originally scheduled to be held in Tulsa 18–22 April. The paper has not been peer reviewed. Carbon dioxide (CO2) storage through CO2 enhanced oil recovery (EOR) has been considered an option for larger-scale deployment of CO2 storage because of the economic benefits of oil recovery, 45Q tax credits, and the use of existing infrastructure. The complete paper investigates how optimal reservoir management and operation strategies can be used to optimize both CO2 storage and oil recovery. Results of the authors’ study showed that joint optimization of well completions and well controls can achieve a higher final net present value (NPV) than that obtained from the optimization of well controls only. Introduction In CO2 EOR associated with storage processes, poorly designed well-operating conditions or completions can lead to low oil recovery factors and suboptimal CO2 storage. Co-optimization of oil production and CO2 storage has been recognized as a feasible technique to maximize benefit in terms of oil production and CO2 storage tax credit. To the best of the authors’ knowledge, settings for well completions have not been considered as optimization variables in a CO2 EOR and storage co-optimization process. The objective of this study is to conduct joint optimization of well completions and controls [well rates or bottomhole pressures (BHP)] that maximize life-cycle NPV in CO2 EOR and storage processes and demonstrate the superiority of joint optimization over well-control-only optimization. Optimization Problem In this study, the optimization problem considered is the joint optimization of well completions and well controls for a CO2 EOR and storage process. The mathematical process behind this determination is detailed in the complete paper. The optimization problem was focused on jointly estimating the well completions (i.e., fraction of injection/production well perforations in each reservoir layer) and CO2 injection and oil-production controls that maximize NPV in a CO2 EOR and storage operation. The authors used a newly developed stochastic simplex approximate gradient algorithm to solve the optimization problem. The performance of the joint optimization approach was compared with the performance of the well-control-only optimization approach. In addition, the performance of the co-optimization of CO2 storage and oil-recovery approach was compared with that of the maximization of only-CO2-storage and only-oil-recovery approaches.

Modeling Evaluates CO2 EOR, Storage Potential in Depleted Reservoirs

2021 ◽  
Vol 73 (06) ◽  
pp. 63-64
Author(s):  
Judy Feder
Keyword(s):  
Continental Shelf ◽  
Oil Recovery ◽  
Co2 Storage ◽  
Gas Injection ◽  
Capital Expenditures ◽  
Recoverable Reserves ◽  
Co2 Eor ◽  
Storage Potential ◽  
And Storage ◽  
Norwegian Continental Shelf

This article, written by JPT Technology Editor Judy Feder, contains highlights of paper SPE 200560, “CO2-EOR and Storage Potentials in Depleted Reservoirs in the Norwegian Continental Shelf,” by Elhans Imanovs, SPE, and Samuel Krevor, SPE, Imperial College London, and Ali Mojaddam Zadeh, Equinor, prepared for the 2020 SPE Europec featured at the 82nd EAGE Conference and Exhibition, originally scheduled to be held in Amsterdam, 8–11 June. The paper has not been peer reviewed. A combination of carbon dioxide (CO2) enhanced oil recovery (EOR) and storage schemes could offer an opportunity to produce additional oil from depleted reservoirs and permanently store CO2 in the subsurface in an economically efficient manner. The complete paper evaluates the effect of different injection methods on oil recovery and CO2 storage potential in a depleted sandstone reservoir in the Norwegian Continental Shelf (NCS). The methods include continuous gas injection (CGI), continuous water injection (CWI), water alternating gas (WAG), tapered WAG (TWAG), simultaneous water above gas coinjection (SWGCO), simultaneous water and gas injection (SWGI), and cyclic SWGI. CO2 EOR and Storage in the NCS In recent years, the number of newly explored fields in the NCS has decreased. Approximately 47% of total resources in the NCS have been produced, and approximately 20% of resources are estimated as recoverable reserves. To fill in the gap between energy demand and recoverable reserves, EOR methods could be employed. One of the most efficient EOR methods is CO2 injection, because complete microscopic sweep efficiency can be achieved, leading to a total depletion of the reservoir. The three major types of CO2 EOR processes—miscible, near-miscible, and immiscible—are described and discussed in the full paper. Four primary CO2-trapping mechanisms are used in the subsurface: structural/stratigraphic, solubility, residual, and mineral trapping. The main locations for underground geological storage are depleted oil and gas reservoirs, coal formations, and saline aquifers. Currently, underground CO2 storage is believed to be a major technology to dramatically reduce CO2 amounts in the atmosphere. According to the International Energy Agency, 54 major oil basins around the world have the potential to produce 75 Bsm3 of additional oil and store 140 Gt of CO2. CO2 EOR and storage projects in the NCS could have several benefits. First, surface and subsea facility availability in the NCS region reduces capital expenditures. Second, in addition to the revenue from extra oil production, carbon credits could be awarded for the CO2 storage. The main challenges of CO2 EOR and storage offshore projects are high operational and capital expenditures. In depleted reservoirs, these include modification of offshore platform materials; additional power supply for CO2 compression and recycling; and replacement of the tubing because wet CO2 is highly corrosive, resulting in scale, asphaltene, and hydrates formation. Contamination of a gas cap with injected CO2 might lead to loss of hydrocarbon gas market value. Only one CO2 EOR project has been implemented offshore—the Lula field in Brazil’s Santos Basin—meaning that industry has very limited experience in such projects.

Experiments and Simulation on Integrated Approach of CO2 EOR and Storage in Mature Reservoirs

2021 ◽  
Author(s):  
Rui Wang ◽  
Chengyuan Lv ◽  
Xuan Liu ◽  
Yongqiang Tang ◽  
Maolei Cui ◽  
...  
Keyword(s):  
Numerical Simulation ◽  
Oil Recovery ◽  
Co2 Storage ◽  
Retention Factor ◽  
Injection Rate ◽  
Permeability Change ◽  
Production Parameters ◽  
Water Partition Coefficient ◽  
Co2 Eor ◽  
And Storage

Abstract CO2 storage mechanisms in an EOR process in mature reservoirs are measured to determine three types of storage factors, which are introduced into compositional numerical simulation. The hybrid objective function coupli ng the oil recovery factor and the CO2 storage ratio is proposed to optimize the injection and production parameters in CO2 flooding. Three storage factors of the oil and water partition coefficient, the permeability change coefficient and the CO2 retention factor are measured in a laboratory, which is utilized to modify the grid properties of oil, brine, rock in compositional numerical simulation. The restart procedure is automatically adopted to consider these storage mechanisms in CO2 EOR. The bi-objective function of the oil recovery factor and the CO2 storage ratio is used to optimize the injection and production parameters for CO2 EOR, which concludes the design principles on CO2 EOR and storage. The oil and water partition coefficient defined as the ratio of the CO2 solubility in the oil phase and the brine phase is a constant for a specific reservoir condition. The permeability change coefficient caused by the mineral dissolution effect of carbonate water decreases slightly in the early stage and increases gradually with the long term injection. The CO2 retention factor that is induced by the relative permeability hysteresis decreases with the pressure and the permeability. These equivalent treated methods that modify fluids and rock in the real-time are inserted into the procedure of compositional numerical simulation to take into account the storage mechanisms in CO2 EOR. The results show that the effect of the storage mechanisms on EOR is evident. Furthermore, the bi - objective optimization indicates that the injection rate should be reduced largely in the medium and the later stages to control gas channeling as the EOR scenario is focused. And the bottom wellhole pressure of producers should be decreased to the lower level to maximize oil recovery. As the storage scenario is concentrated, the injection rate is required to be slightly controlled. As the producers are shut off, the injection rate must be increased significantly to maximize CO2 storage. The storage mechanisms in the CO2 EOR process have not been understood thoroughly. The methodology of numerical simulation coupling CO2 EOR and storage is not mature, which is still not taken into account in commercial software. The results above provide a way to optimize CO2 EOR and storage simultaneously, which is significant for the large scale storage after CO2 EOR in mature oilfield.

scholarly journals Social aspects of Total’s Lacq CO2 capture, transport and storage pilot project

2011 ◽  
Vol 4 ◽  
pp. 6263-6272 ◽  
Author(s):  
Minh Ha-Duong ◽  
Michèle Gaultier ◽  
Benoît deGuillebon
Keyword(s):  
Co2 Capture ◽  
Pilot Project ◽  
Social Aspects ◽  
And Storage

Research Trends of Carbon Dioxide Capture using Ionic Liquids and Aqueous Amine-Ionic Liquids Mixtures

2016 ◽  
Vol 13 (1) ◽  
pp. 53
Author(s):  
Siti Nabihah Jamaludin ◽  
Ruzitah Mohd Salleh
Keyword(s):  
Ionic Liquids ◽  
Co2 Capture ◽  
Membrane Separation ◽  
Carbon Dioxide Capture ◽  
Global Climate ◽  
Research Trends ◽  
Co2 Absorption ◽  
Absorption Process ◽  
Chemical Absorption ◽  
Factors Influencing

Anthropogenic CO2 emissions has led to global climate change and widely contributed to global warming since its concentration has been increasing over time. It has attracted vast attention worldwide. Currently, the different CO2 capture technologies available include absorption, solid adsorption and membrane separation. Chemical absorption technology is regarded as the most mature technology and is commercially used in the industry. However, the key challenge is to find the most efficient solvent in capturing CO2. This paper reviews several types of CO2 capture technologies and the various factors influencing the CO2 absorption process, resulting in the development of a novel solvent for CO2 capture.

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