Oil Recovery by In-Situ Gas Generation: Volume and Pressure Measurements

Bakhtiyarov, Sayavur I.; Shakhverdiyev, Azizaga Kh.; Panakhov, Geilani M.; Abbasov, Eldar M.

doi:10.1115/fedsm2006-98359

Cited by 5 publications

(5 citation statements)

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“…2, curves 1 and 2). If in the reaction there is diffusion of additional gas into the medium, as noted by the authors Bakhtiyarov et al (2006), Chukwuma (1983), , Riazi (1996), the pressure drop at the final stage of gas release is due to diffusion of gas bubbles from the medium into the liquid. In this case, the ratio of formation and dissolution of gas bubbles is written as follows:…”

Section: Kinetics Of Gas Generationmentioning

confidence: 97%

“…Since the 1930s, many studies of the gas diffusion coefficient in liquids have been carried out Bakhtiyarov et al (2006), Chukwuma (1983), Dake (1998), Ferer & Smith (1994), Li & Chen (2023), Mandrik et al (2010), Panakhov & Abbasov (2004), Panakhov & Omrani (2008), . Most of them were carried out using adsorption or diffusion PVT (pressure-volumetemperature) units.…”

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

“…Aqueous solutions of various chemical agents are also used at the final stages of oil field development to increase the displacement efficiency during waterflooding and to recover residual oil reserves from stagnant reservoir zones. Currently, the technology of enhanced oil recovery by using carbon dioxide as a displacing agent is one of the most effective and is aimed at the recovery of hard-to-recover oil reserves, as it noted in Bakhtiyarov et al (2006) ;Ferer & Smith (1994); Mandrik et al (2010); Gasimov et al (2019). The distribution of injected CO 2 gas in oil saturated porous media is crucial for risk assessment and prediction of carbon dioxide application.…”

Section: Introductionmentioning

confidence: 99%

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Modelling of Internal Transformations of Gas Phase in Porous Media

Panahov

2024

AMMA

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The paper presents the research of temperature change in the investigated medium during dynamic expansion of gas (CO2) generated in reservoir conditions, diffusion of carbon dioxide into the displacing fluid and their influence on the displacement process. In-situ gas generation can provide a way to control the nonequilibrium fractal state at the interface under displacement in a porous medium. The change from fractal growth to non-fractal growth can be characterised as a function of density and viscosity ratios. This effect is shown in the increase of hydrocarbon displacement coefficient due to the equalisation of densities of displacing and displaced agents as a consequence of the increase in gas saturation of the fluid.

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Section: Kinetics Of Gas Generationmentioning

confidence: 97%

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Modelling of Internal Transformations of Gas Phase in Porous Media

Panahov

2024

AMMA

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“…In [35], information is provided on an experimental setup that allows one to regulate the reaction temperature and record the volume and pressure of the gas formed. Experimental studies were also carried out on the influence of formation fluid salinity on the parameters (volume and pressure) of the generated gas.…”

Section: Co2 Generation In Reservoir Conditionsmentioning

confidence: 99%

Approaches to the effective implementation of SWAG-technology and technology for intrastratal carbon dioxide generating

Gorelkina

2024

E3S Web Conf.

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This article provides an overview of the results of studies of water-gas methods and carbon dioxide generation in reservoir conditions as methods for increasing oil recovery. It is shown that the efficiency of technology implementation is influenced by the choice of technical device and the composition of the selected agents selected for injection into the reservoir. The effectiveness of the implementation of these methods is directly influenced by reservoir conditions (pressure and temperature), as well as the mineralization composition of the liquid phase (injected in the form of a water-gas mixture or formation water). It turned out that in the case of an optimal mineralization composition of the liquid, the technological efficiency of the methods increases. In other cases, it is necessary the composition and concentration of surfactants are given. Recommendations on the composition and concentration of surfactants are given. To implement methods in a specific field, it is recommended to conduct laboratory studies to determine the optimal composition of the agent acting on hydrocarbon-saturated rock.

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“…Laboratory and field test results showed that additional oil was produced due to application of the in-situ CO 2 system compared with conventional waterflooding. Bakhtiyarov et al [9] investigated the effect of water salinity on gas volume and pressure of the generated CO 2 . Results showed that the intensity of the generated gas increased with water salinity.…”

Section: Introductionmentioning

confidence: 99%

Experimental Study of In‐Situ CO₂Foam Technique and Application in Yangsanmu Oilfield

Jin

Liu

et al. 2016

J Surfact & Detergents

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The Yangsanmu oilfield of Dagang is a typical heavy oil reservoir. After the maximum primary production (waterflooding), more than half of the original oil is still retained in the formation. Therefore, the implementation of an enhanced oil recovery (EOR) process to further raise the production scheme is inevitable. In this work, a novel in‐situ CO2 foam technique which can be used as a potential EOR technique in this oilfield was studied. A screening of gas producers, foam stabilizers and foaming agents was followed by the study of the properties of the in‐situ CO2 foam systems through static experiments. Core‐flooding experiments and field application were also conducted to evaluate the feasibility of this technique. The results indicated that the in‐situ CO2 foam system can improve both the sweep and displacement efficiencies, due to the capacity of this system in reducing oil viscosity and interfacial tension, respectively. The EOR performance of the in‐situ CO2 foam system is better than the single‐agent and even binary system (surfactant‐polymer) flooding. The filed data demonstrated that the in‐situ CO2 technique can significantly promote oil production and control water cuts. These results are believed to be beneficial in making EOR strategies for similar reservoirs.

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Oil Recovery by In-Situ Gas Generation: Volume and Pressure Measurements

Cited by 5 publications

References 0 publications

Modelling of Internal Transformations of Gas Phase in Porous Media

Modelling of Internal Transformations of Gas Phase in Porous Media

Approaches to the effective implementation of SWAG-technology and technology for intrastratal carbon dioxide generating

Experimental Study of In‐Situ CO₂Foam Technique and Application in Yangsanmu Oilfield

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Oil Recovery by In-Situ Gas Generation: Volume and Pressure Measurements

Cited by 5 publications

References 0 publications

Modelling of Internal Transformations of Gas Phase in Porous Media

Modelling of Internal Transformations of Gas Phase in Porous Media

Approaches to the effective implementation of SWAG-technology and technology for intrastratal carbon dioxide generating

Experimental Study of In‐Situ CO2Foam Technique and Application in Yangsanmu Oilfield

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Experimental Study of In‐Situ CO₂Foam Technique and Application in Yangsanmu Oilfield