Simulation of Immiscible Water-Alternating-CO2 Flooding in the Liuhua Oilfield Offshore Guangdong, China

Hu, Gang; Li, Pengchun; Yi, Linzi; Zhao, Zhongxian; Tian, Xuanhua; Liang, Xi

doi:10.3390/en13092130

Cited by 7 publications

(1 citation statement)

References 21 publications

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“…To understand this process, it is necessary to evaluate the SC‐CO 2 migration characteristics in the formation filled previously with injected water. Meanwhile, the initial effective confining pressure (ECP) distribution inside the formation would be affected by the water injection, resulting in a change in local porosity and permeability 11,12 . This has a significant influence on the SC‐CO 2 plume and migration characteristics, thereby making it more important to understand the SC‐CO 2 drainage processes under different ECPs.…”

Section: Introductionmentioning

confidence: 99%

The effects of porosity and permeability changes on simulated supercritical CO₂ migration front in tight glutenite under different effective confining pressures from 1.5 MPa to 21.5 MPa

Myers

et al. 2020

Greenhouse Gases

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Depending on rock pore compressibility, a change in effective confining pressure (ECP) can have a significant influence on supercritical CO 2 (SC-CO 2) migration characteristics in natural reservoirs. In this study, a tight glutenite sample was used to conduct porosity/permeability measurements under different ECPs of 1.5, 5.5, 9.5, 13.5, 17.5 and 21.5 MPa. Then a SC-CO 2 drainage core flooding experiment, which was monitored using nuclear magnetic resonance (NMR) technique, was conducted at an ECP of 5.5 MPa. Measurement results show that the porosity and permeability of the sample were comparatively low (at an ECP of 1.5 MPa, 8.3% and 2.4 mD, respectively). With increasing ECP, the porosity/permeability decreased rapidly initially then more slowly at the larger ECP value. NMR results shows that SC-CO 2 preferentially displaced water creating flow channels inside the sample. At SC-CO 2 breakthrough, the average residual water saturation was 69.86%. Following breakthrough, SC-CO 2 continued to displace the water creating more substantial flow channels until they were sufficient to transport the SC-CO 2 at the fixed flow rate, resulting in a residual water saturation of 42.72%. A two-dimensional computational model was then established based on these experimental results to simulate the fluid behaviors at an ECP of 5.5 MPa, and then the model was

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Section: Introductionmentioning

confidence: 99%

The effects of porosity and permeability changes on simulated supercritical CO₂ migration front in tight glutenite under different effective confining pressures from 1.5 MPa to 21.5 MPa

Myers

et al. 2020

Greenhouse Gases

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The novel technology for reservoir stimulation: in situ generation of carbon dioxide for the residual oil recovery

Panahov

Abbasov

Jiang³

2021

J Petrol Explor Prod Technol

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The gas and chemical flooding for reservoir stimulation with residual hydrocarbons reserves are highly relevant problem of current oil and gas recovery strategy. The objective of this paper is laboratory study and field implementation of new gas-EOR technology—in situ carbon dioxide generation technique for CO2-liquid slug formation under oil displacement, increasing the reservoir sweep efficiency and residual oil recovery. This paper presents a summary of a wide range of laboratory tests conducted on different core samples and chemical compositions. Several physical and hydrodynamic phenomena of in situ CO2 generation in highly permeable zones of a porous medium have been investigated as a part of complex study, which involved laboratory tests on the field-scale industrial technology applications, determination of optimal concentrations of foaming agents and inhibiting additives in gas-releasing solutions, etc. The results of laboratory experiments showed that the incremental recovery ranged between 30 and 35% oil original in place. The unique results of the field implementation provide developing an optimal technological scheme of reservoir stimulation with residual oil reserves both onshore and offshore oil fields. Technology of in situ CO2 generation was applied on the group of wells on Penglai offshore oil field (Bohai Bay). Incremental oil production for field operation was 37,740 bbl of crude oil. Theoretical and laboratory studies, as well as the outcomes of industrial implementation of a new method of residual oil recovery, using a CO2-slug confirm technology and economic profitability of the proposed solution.

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Accelerated optimization of CO2-miscible water-alternating-gas injection in carbonate reservoirs using production data-based parameterization

Santos

Fioravanti

Botechia

et al. 2023

J Petrol Explor Prod Technol

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Enhancing oil recovery in reservoirs with light oil and high gas content relies on optimizing the miscible water alternating gas (WAG) injection profile. However, this can be costly and time-consuming due to computationally demanding compositional simulation models and numerous other well control variables. This study introduces WAGeq, a novel approach that expedites the convergence of the optimization algorithm for miscible water alternating gas (WAG) injection in carbonate reservoirs. The WAGeq leverages production data to create flexible solutions that maximize the net present value (NPV) of the field, while providing practical implementation of individual WAG profiles for each injector. The WAGeq utilizes an injection priority index to rank the wells and determine which should inject water or gas at each time interval. The index is built using a parametric equation that considers factors such as producer and injector relationship, water cut (WCUT), gas–oil ratio (GOR), and wells cumulative gas production, to induce desirable effects on production and WAG profile. To evaluate WAGeq’s effectiveness, two other approaches were compared: a benchmark solution named WAGbm, in which the injected fluid is optimized for each well over time, and a traditional baseline strategy with fixed 6-month WAG cycles. The procedures were applied to a synthetic simulation case (SEC1_2022) with characteristics of a Brazilian pre-salt carbonate field with karstic formations and high CO2 content. The WAGeq outperformed the baseline procedure, improving the NPV by 6.7% or 511 USD million. Moreover, WAGeq required fewer simulations (less than 350) than WAGbm (up to 2000), while delivering a slightly higher NPV. The terms of the equation were also found to be essential for producing a WAG profile with regular patterns on each injector, resulting in a more practical solution. In conclusion, WAGeq significantly reduces computational requirements while creating consistent patterns across injectors, which are crucial factors to consider when planning a practical WAG strategy.

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Simulation of Immiscible Water-Alternating-CO2 Flooding in the Liuhua Oilfield Offshore Guangdong, China

Cited by 7 publications

References 21 publications

The effects of porosity and permeability changes on simulated supercritical CO₂ migration front in tight glutenite under different effective confining pressures from 1.5 MPa to 21.5 MPa

The effects of porosity and permeability changes on simulated supercritical CO₂ migration front in tight glutenite under different effective confining pressures from 1.5 MPa to 21.5 MPa

The novel technology for reservoir stimulation: in situ generation of carbon dioxide for the residual oil recovery

Accelerated optimization of CO2-miscible water-alternating-gas injection in carbonate reservoirs using production data-based parameterization

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Simulation of Immiscible Water-Alternating-CO2 Flooding in the Liuhua Oilfield Offshore Guangdong, China

Cited by 7 publications

References 21 publications

The effects of porosity and permeability changes on simulated supercritical CO2 migration front in tight glutenite under different effective confining pressures from 1.5 MPa to 21.5 MPa

The effects of porosity and permeability changes on simulated supercritical CO2 migration front in tight glutenite under different effective confining pressures from 1.5 MPa to 21.5 MPa

The novel technology for reservoir stimulation: in situ generation of carbon dioxide for the residual oil recovery

Accelerated optimization of CO2-miscible water-alternating-gas injection in carbonate reservoirs using production data-based parameterization

Contact Info

Product

Resources

About

The effects of porosity and permeability changes on simulated supercritical CO₂ migration front in tight glutenite under different effective confining pressures from 1.5 MPa to 21.5 MPa

The effects of porosity and permeability changes on simulated supercritical CO₂ migration front in tight glutenite under different effective confining pressures from 1.5 MPa to 21.5 MPa