A Comprehensive Project of Thermal, Gas and Chemical EOR Method Application for Bazhenov Shale Formation

Ushakova, A. S.; Mukhina, Elena; Scerbacova, Alexandra; Turakhanov, Aman; Bakulin, D. A.; Kasyanenko, Anton

doi:10.2118/206424-ms

Cited by 3 publications

(1 citation statement)

References 28 publications

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“…A number of research papers that describe water-and surfactant-based huff-n-puff projects held in the laboratory were published recently. An overview of thermal, gas, and chemical EOR for shale formation was discussed by Ushakova et al 36 The current project is focused on the investigation of the water and surfactant huff-n-puff process in a shale reservoir by experimental work and simulation studies. The permeability of the cores used was less than 1 μD, the reservoir temperature was 110 °C, and the pressure was 23.4 MPa.…”

Section: Introductionmentioning

confidence: 99%

Water- and Surfactant-Based Huff-n-Puff Injection into Unconventional Liquid Hydrocarbon Reservoirs: Experimental and Modeling Study

et al. 2023

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The combination of horizontal well drilling and multistage hydraulic fracturing is currently the leading method for developing shale reservoirs. However, oil recovery from these techniques does not exceed 10%, and supporting technologies are being sought. The injection of water or surfactant solutions in huff-n-puff mode is often considered an enhanced oil recovery option for shales, which can be used alone or in combination with other technologies, such as CO2 injection. This study presents experimental and numerical investigations into the huff-n-puff treatment of low-permeability shale cores using water-based compositions. Additionally, an attempt was made to displace oil by applying a nanofluid booster. Computational tomography was used as one of the methods to determine the oil recovery factor. Two core flooding tests with different designs and injection fluids were conducted. The first experiment involved brine filtration in one direction, followed by nanofluid injection. Second core flooding/huff-n-puff test implied injection of a 0.5 wt % surfactant solution. The results showed that the oil recovery factor achieved using brine was approximately 50% and decreased after nanofluid injection until 31%. Besides that, there was no significant effect from the use of the surfactant. At the same time, critical issues were observed regarding a decrease in core permeability. A numerical simulation of the second experiment was performed to restore the relative phase permeability (RPP) in the surfactant–oil system and to study the dependency of the capillary number logarithm on the miscibility coefficient. The simulation showed a good convergence in terms of the recovery factor values, with an error of ∼1.5%.

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Section: Introductionmentioning

confidence: 99%

Water- and Surfactant-Based Huff-n-Puff Injection into Unconventional Liquid Hydrocarbon Reservoirs: Experimental and Modeling Study

et al. 2023

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Identification of the Composition and Assessment of the Influence of the Solid Hydrocarbon Phase in the Reservoir on the Behavior of the Mobile Fluid of the Bazhenov Formation During the Reservoir Development

Yushchenko,

Sannikova,

Kulkov

et al. 2024

Georesursy

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The purpose of the work is to identify the composition of the initial reservoir hydrocarbon (HC) system of the Bazhenov formation, as well as to assess the influence of the presence of a heavy solid hydrocarbon phase (bitumen) in the formation on the production of mobile fluids using PVT modeling methods. The article describes the necessary experiments to determine the component composition of the C81+ fraction and the PVT properties of the formation mobile fluid taken from the well and the bitumen extract from the rock, and also presents their results. In addition, the properties of fractions up to C81+ were calculated depending on the molecular weight for PVT modeling (extension of the Katz-Firuzabadi table). One of the important parts of the article is the assessment of the ratio of bound and free oil in the original reservoir system. Based on geochemical research data, an analysis was performed to assess the component composition of the original system (using the example of the Bazhenov Formation) using rock pyrolysis and studying formation fluid and bitumen. Using the results of studies of reservoir fluid samples, a PVT model was built and tuned. This PVT model was used to assess the properties of the initial reservoir hydrocarbon system and was adjusted to the fraction of the solid phase in the reservoir at the initial reservoir conditions. After this, based on the PVT model, an assessment was made of the influence of the presence of a solid phase in the composition of the reservoir system on the behavior of a mobile hydrocarbon fluid during reservoir development for depletion, as well as on the use of enhanced oil recovery methods (injection of associated petroleum gas and thermal methods of influencing the reservoir).

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Chemical EOR Efficiency for Ultra-Low Permeable Shale Deposits

Ushakova

Groman

Kasyanenko

et al. 2022

Day 3 Wed, November 02, 2022

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The purpose of the article is the search and development of water-soluble chemicals for the successful drainage and impregnation of low-permeable shale oil formations. The main problem for shale oil deposits is ultra-low water permeability. We are dealing with the cores of the Bazhenov formation, which have permeability of 10 mkD, nano-porous matrix with natural cracks. In the paper we have collected and examined the mechanisms that prevent water from penetrating into core samples with low permeability, and suggest chemicals that can help overcome this problem. Complexes of different surfactants, polysurfactants, nanoparticles with modified surface were investigated. Wettability, interfacial tension measurements, adsorption, micelles formation and phase behavior experiments were held in order to select the most effective chemical agent. A "funnel" of experimental search was performed and two best surfactants and composition of surfactant with nanoparticles was figured out. Then, for the first time, displacement experiments were carried out through the consolidated core samples of the Bazhenov formation, and the displacement efficiency of 53% was obtained. Due to the fact that the injection pressure turned out to be very high, and there were also problems associated with the adsorption of surfactants. The further steps to improve the experimental study were discussed.

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A Comprehensive Project of Thermal, Gas and Chemical EOR Method Application for Bazhenov Shale Formation

Cited by 3 publications

References 28 publications

Water- and Surfactant-Based Huff-n-Puff Injection into Unconventional Liquid Hydrocarbon Reservoirs: Experimental and Modeling Study

Water- and Surfactant-Based Huff-n-Puff Injection into Unconventional Liquid Hydrocarbon Reservoirs: Experimental and Modeling Study

Identification of the Composition and Assessment of the Influence of the Solid Hydrocarbon Phase in the Reservoir on the Behavior of the Mobile Fluid of the Bazhenov Formation During the Reservoir Development

Chemical EOR Efficiency for Ultra-Low Permeable Shale Deposits

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