Quantifying Pore Size Distribution Effect on Gas in Place and Recovery Using SLD-PR EOS for Multiple-Components Shale Gas Reservoir

2015 ◽  
Author(s):  
Brandon T. Tolbert ◽  
Xingru Wu
Keyword(s):  
Pore Size Distribution ◽  
Pore Size ◽  
Size Distribution ◽  
Shale Gas ◽  
Gas Reservoir ◽  
Shale Gas Reservoir ◽  
Multiple Components ◽  
Distribution Effect

scholarly journals Review of Formation and Gas Characteristics in Shale Gas Reservoirs

Energies ◽  
2020 ◽  
Vol 13 (20) ◽  
pp. 5427
Author(s):  
Boning Zhang ◽  
Baochao Shan ◽  
Yulong Zhao ◽  
Liehui Zhang
Keyword(s):  
Pore Size Distribution ◽  
Pore Size ◽  
Size Distribution ◽  
Shale Gas ◽  
Physical Parameters ◽  
Gas Reservoirs ◽  
Shale Formations ◽  
Adsorbed Gas ◽  
Shale Gas Reservoirs ◽  
Longmaxi Shale

An accurate understanding of formation and gas properties is crucial to the efficient development of shale gas resources. As one kind of unconventional energy, shale gas shows significant differences from conventional energy ones in terms of gas accumulation processes, pore structure characteristics, gas storage forms, physical parameters, and reservoir production modes. Traditional experimental techniques could not satisfy the need to capture the microscopic characteristics of pores and throats in shale plays. In this review, the uniqueness of shale gas reservoirs is elaborated from the perspective of: (1) geological and pore structural characteristics, (2) adsorption/desorption laws, and (3) differences in properties between the adsorbed gas and free gas. As to the first aspect, the mineral composition and organic geochemical characteristics of shale samples from the Longmaxi Formation, Sichuan Basin, China were measured and analyzed based on the experimental results. Principles of different methods to test pore size distribution in shale formations are introduced, after which the results of pore size distribution of samples from the Longmaxi shale are given. Based on the geological understanding of shale formations, three different types of shale gas and respective modeling methods are reviewed. Afterwards, the conventional adsorption models, Gibbs excess adsorption behaviors, and supercritical adsorption characteristics, as well as their applicability to engineering problems, are introduced. Finally, six methods of calculating virtual saturated vapor pressure, seven methods of giving adsorbed gas density, and 12 methods of calculating gas viscosity in different pressure and temperature conditions are collected and compared, with the recommended methods given after a comparison.

Adsorption-Induced Deformation of Microporous Carbons: Pore Size Distribution Effect

Langmuir ◽  
2008 ◽  
Vol 24 (13) ◽  
pp. 6603-6608 ◽  
Author(s):  
Piotr Kowalczyk ◽  
Alina Ciach ◽  
Alexander V. Neimark
Keyword(s):  
Pore Size Distribution ◽  
Pore Size ◽  
Size Distribution ◽  
Microporous Carbons ◽  
Distribution Effect

scholarly journals Integration of NMR, Conventional Logs and Core Data to Improve Formation Evaluation of a Gas Reservoir in Kangan and Dalan Formation, Iran

2014 ◽  
Vol 5 (1) ◽  
pp. 154-168
Author(s):  
Ali Mohammad Bagheri ◽  
Mohammad Mohammadnia ◽  
Ghafor Karimi
Keyword(s):  
Pore Size Distribution ◽  
Pore Size ◽  
Size Distribution ◽  
Well Logs ◽  
Logarithmic Mean ◽  
Reservoir Properties ◽  
Gas Reservoir ◽  
Technical Problems ◽  
Conventional Logs

Conventional log based reservoir characterization of a gas reservoir in the Kangan and Dalan formations have recently been improved by application of the nuclear magnetic resonance log (NMR).    Important reservoir properties such as permeability, pore size distribution and capillary pressure curves can be estimated from NMR. These parameters are simulated directly in the laboratory on core samples recovered from the reservoir. Due to high cost associated with coring and some technical problems, few wells in any given field are cored.    The only problem of NMR measurements in gas reservoirs is that in gas-bearing zones, total NMR porosity read much less than actual porosity due to low hydrogen index of the gas. This problem was solved by integration of NMR porosity with conventional well logs such as density and sonic and compared with core porosity. Improved porosity calculation lead to better core independent permeability estimation on the wells logged with NMR.     NMR T2 distribution was calibrated with laboratory derived pore size distribution in 7 samples and a constant scaling factor was derived for each rock type to predict a pseudo pore size distribution from NMR. Logarithmic mean of pore size distribution in 4 wells with NMR was integrated with conventional logs in an artificial neural network to predict a pseudo pore size distribution logarithmic mean (PPSDLM) in the wells without NMR.    PPSDLM and conventional well logs were involved to an electrofacies modeling to predict electrofacies in the reservoir for characterization of heterogeneity of the reservoir in 3D geological model. NMR permeability was also imported to the model as an associated log to predict facies base permeability.    To test the permeability prediction, estimated permeability was compared with core derived permeability on 2 cored wells to see how well, estimated permeability fitted the actual core permeability.

Quantitative characterization and characteristic analysis of pore structure of shale-gas reservoir in the Sichuan Basin, China

2019 ◽  
Vol 7 (4) ◽  
pp. SJ23-SJ32 ◽  
Author(s):  
Huaimin Dong ◽  
Jianmeng Sun ◽  
Jinjiang Zhu ◽  
Zhenzhou Lin ◽  
Likai Cui ◽  
...  
Keyword(s):  
Pore Structure ◽  
Pore Size Distribution ◽  
Pore Size ◽  
Size Distribution ◽  
Conversion Coefficient ◽  
Gas Reservoir ◽  
Quantitative Characterization ◽  
Hybrid Detection ◽  
The Sichuan Basin ◽  
Aperture Distribution

Quantitative characterization of pore structure in shale can provide basic parameters for evaluation of the shale-gas reservoir quality. However, it is difficult to use conventional methods to accurately and comprehensively characterize the pore structure parameters. We take shale samples from the Longmaxi Formation in the Sichuan Basin as the study object, and we use the high-pressure mercury intrusion, nitrogen adsorption, and carbon dioxide adsorption methods to characterize the whole aperture distribution. We found that the pore size in shale is positively related to the transverse relaxation time ([Formula: see text] value) and there exists a conversion coefficient. We have developed a new method combining nuclear magnetic resonance (NMR) with hybrid detection methods for testing the pore size distribution, and we optimized the conversion coefficient between pore size obtained by a hybrid detection method and the [Formula: see text] value. NMR can then characterize the pore size distribution by conversion coefficient. This method can effectively make up for the deficiency of conventional methods for pore size distribution characterization by a single method. Our results indicate that the macropore, mesopore, and micropore in shale are very developed, and the pore shapes are ink bottle and slit-like. Shale pores mainly consist of mesopore and micropore, contributing to approximately 74.33% of pore volume, whereas micropore contributes approximately 70.18% of specific surface area (SSA). Therefore, the macropore has a limited effect on the pore volume and SSA. In addition, the establishment of whole aperture distribution characterization by the new method can more comprehensively reflect the actual pore distribution in shale.

Investigating Effects of Pore Size Distribution and Pore Shape on Radon Production in Marcellus Shale Gas Formation

2019 ◽  
Vol 33 (2) ◽  
pp. 700-707
Author(s):  
Wei Tian ◽  
Xingru Wu ◽  
Dehua Liu ◽  
Amanda Knaup ◽  
Changlong Chen ◽  
...  
Keyword(s):  
Pore Size Distribution ◽  
Pore Size ◽  
Size Distribution ◽  
Shale Gas ◽  
Marcellus Shale ◽  
Pore Shape ◽  
Gas Formation
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