Evaluation of the effects of homogenizing matrix block sizes on the simulation of naturally fractured reservoirs

Aghabarari, Amirhossein; Ghaedi, Mojtaba

doi:10.1016/j.petrol.2022.110373

Cited by 4 publications

(4 citation statements)

References 15 publications

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“…This final situation provides an appropriate potential for acid gas storage. Moreover, a remarkable volume of trapped oil can be produced under the gas injection process 55 …”

Section: Methodsmentioning

confidence: 99%

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Mechanistic analysis of acid gas storage and oil recovery in naturally fractured reservoirs using single matrix block approach

Shirzad,

Sadeghzadeh,

Assareh

2024

Greenhouse Gases

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The objective of this study is to assess the storage of acid gas, containing CO2 and H2S, in a depleted naturally fractured reservoir (NFR) using single matrix block (SMB) approach. The acid gas dissolution in oil is considered by Peng‐Robinson equation of state and compositional simulation. The PHREEQC package is used to determine acid gas solubility in formation brine. Three types of acid gases with different compositions are used for this study and their swelling behavior and miscibility in relation to the reservoir oil are analyzed. An SMB model, with a matrix block surrounded by fractures, is constructed, and validated for simulation of a real experiment. The simulation is conducted for synthetic and real reservoir fluids when the oil is in its residual saturation. A sensitivity analysis is performed to study the effects of key parameters, such as acid gas composition, reservoir pressure, permeability, porosity and matrix height on the storage capacity and oil recovery factor. The matrix has a volume of 27 m3 and about half of acid gas storage is achieved in the first 5 years while the simulations are run for 30 years. The results show that up to 90% of remained oil is recoverable, and more than 0.67 kmol of acid gas per cubic meter of matrix is stored whether matrix contains a real oil or a synthetic one. Higher storage is achieved for higher matrix porosities and heights and large H2S proportion in acid gas. In all cases about 10% of acid gas is trapped in water and the remaining 90% is dissolved in oil. The mineral trapping was more active in CO2‐rich acid gases. While about 10 kg of the matrix rock was dissolved in the acidic brine when the acid gas contained H2S, the amount of the dissolved minerals in acidic brine resulted from the injection of CO2‐rich acid gas was more than 16 kg. Finally, this study gives a comparative analysis of the storage performance of acid gas mixture and pure CO2. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…This final situation provides an appropriate potential for acid gas storage. Moreover, a remarkable volume of trapped oil can be produced under the gas injection process 55 …”

Section: Methodsmentioning

confidence: 99%

“…Moreover, a remarkable volume of trapped oil can be produced under the gas injection process. 55 To simulate NFRs, they are usually simplified as 3D rectangular matrixes among a network of fractures. In this study, we aim to assess the capacity of a depleted matrix block in underground acid gas sequestration.…”

Section: Smb Construction Approachmentioning

confidence: 99%

Mechanistic analysis of acid gas storage and oil recovery in naturally fractured reservoirs using single matrix block approach

Shirzad,

Sadeghzadeh,

Assareh

2024

Greenhouse Gases

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“…The pores in coal can be divided into: micropores, small pores, mesopores, macropores and visible pores and fissures [36]. Micropores: diameter < 10 −5 mm, which constitute the adsorption volume in coal; small boreholes [37]: diameter = 10 −5 to 10 −4 mm, which is the space that constitutes capillary condensation and gas diffusion; mesopores: diameter = 10 −4 ~10 −3 mm, which is a laminar permeation interval that constitutes a slow gas; large pore: diameter = 10 −3 to 10 −1 mm, which is a strong laminar permeation interval and a plugging material percolation interval, and is determined to have a strong destruction of structural coal failure surface [38]; visible pores and fissures: diameter > 10 −1 mm, which is the mixed permeation interval of gas laminar flow and turbulent flow, and determines the macroscopic failure surface of coal [39].…”

Section: Influence Of Coal Properties On Processmentioning

confidence: 99%

Determination of Key Technical Parameters in the Study of New Pressure Sealing Technology for Coal Seam Gas Extraction

Sun

Wang

et al. 2022

IJERPH

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Coal is affected by the concentrated stress disturbance of mining, the disturbance of drilling hole formation, and the concentrated stress of coal shrinkage and splitting of gas desorption from the hole wall; these result in a large number of secondary cracks that collect and leak gas. As a result, it is difficult for the coal seam sealing process to meet engineering quality sealing requirements, which results in problems such as low gas concentration during the extraction process. In this paper, based on the analysis of coal pore and fissure characteristics, and in view of the current situation of gas drainage and sealing in this coal seam, combined with the existing grouting and sealing technology, it is proposed to use pressure grouting and sealing to realize the sealing of deep coal bodies in the hole wall. According to the field conditions, the experimental pressure sealing parameter index is as follows: theoretical sealing length L1 = 9.69 m, the sealing length L2 = 13.98 m is verified, and the final sealing length is determined to be 15 m; the sealing radius is determined to be 0.6 m; the cement slurry was prepared on site with a water: cement ratio of 2:1; PG = 0.43 MPa was calculated; the range of the slurry diffusion radius R was 93.4–176.6 cm; the grouting pressure was determined to be 0.516 MPa. Field application practice has proved that: (1) Under the same drilling parameters and sealing parameters, the gas drainage effect of drilling with pressure sealing is 2.3 times higher than that without pressure sealing; (2) Using traditional sealing technology for drilling holes, the gas extraction concentration is far lower than the sealing operation effect of using the pressure sealing process; (3) Reasonably extending the length of the gas extraction drilling and sealing is a basic guarantee for realizing a substantial increase in the gas extraction concentration; (4) Sealing with pressure leads to a reliable and stable hole process.

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“…Literature Review. Modeling of the naturally fractured reservoirs is one of the challenges due to the generation of the complex fractures and the conductivity factor of fractures that afect fuids paths [15]. Although fractures covered 20% of world reserves, naturally fractured reservoirs represented the risk reservoirs in drilling, production, and modeling processes due to fracture pressure that sometimescaused loss in hydrocarbons production [16].…”

Section: Introductionmentioning

confidence: 99%

Fluid Flow Behavior Prediction in Naturally Fractured Reservoirs Using Machine Learning Models

et al. 2023

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The naturally fractured reservoirs are one of the most challenging due to the tectonic movements that are caused to increase the permeability and conductivity of the fractures. The instability of the permeability and conductivity effects on the fluid flow path causes problems during the transfer of the fluids from the matrix to the fractures and fluid losses during production. In addition, these complications made it difficult for engineers to estimate fluid flow during production. The fracture properties’ study is important to model the fluid flow paths such as the fracture porosity, permeability, and the shape factor, which are considered essential in the stability of fluid flow. To examine this, this research introduced new models including decision tree (DT), random forest (RF), K-nearest regression (KNR), ridge regression (RR), and LASSO regression model,. The research studied the fracture properties in naturally fractured reservoirs like the fracture porosity (FP) and the shape factor (SF). The datasets used in this study were collected from previous studies “i.e., Texas oil and gas fields” to build an intelligence-based predictive model for fluid flow characteristics. The prediction process was conducted based on interporosity flow coefficient, storativity ratio, wellbore radius, matrix permeability, and fracture permeability as input data. This study revealed a positive finding for the adopted machine learning (ML) models and was superior in using statistical accuracy metrics. Overall, the research emphasized the implementation of computer-aided models for naturally fractured reservoir analysis, giving more details on the extensive execution techniques, such as injection or the creation of artificial cracks, to minimize hydrocarbon losses or leakage.

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Evaluation of the effects of homogenizing matrix block sizes on the simulation of naturally fractured reservoirs

Cited by 4 publications

References 15 publications

Mechanistic analysis of acid gas storage and oil recovery in naturally fractured reservoirs using single matrix block approach

Mechanistic analysis of acid gas storage and oil recovery in naturally fractured reservoirs using single matrix block approach

Determination of Key Technical Parameters in the Study of New Pressure Sealing Technology for Coal Seam Gas Extraction

Fluid Flow Behavior Prediction in Naturally Fractured Reservoirs Using Machine Learning Models

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