Gassmann's equation and fluid‐saturation effects on seismic velocities

Han, De‐hua; Batzle, Michael

doi:10.1190/1.1707059

Cited by 222 publications

(93 citation statements)

References 17 publications

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“…When the gas saturation is higher than approximately 10%, the P-wave velocity and Vp/Vs are not sensitive to gas saturation and do not change much with increasing gas saturation. It is clear that the S-wave and longitudinal wave velocities significantly decrease when the water layer has some gas [9]. Fig.…”

Section: Comparison Between the Theory And Ex-perimental Results And mentioning

confidence: 90%

An Experimental Study of Velocity-Saturation Relationships in Volcanic Rocks

Liu¹,

Zhao²

2015

TOPEJ

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Abstract:In this paper, experiments are carried out under different pressures and water saturations using core samples of volcanic rocks from the Junggar Basin in China to understand how water saturation affects P-and S-wave velocities. The results show that water saturated rocks exhibit significantly higher P-and S-wave velocities than gas saturated rocks. In addition, the P-and S-wave velocity ratio declines with increasing water saturation. Furthermore, a P-and S-wave velocity ratio vs. resistivity cross plot is created to identify gas reservoirs in the volcanic rocks in the Junggar Basin.

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Section: Comparison Between the Theory And Ex-perimental Results And mentioning

confidence: 90%

An Experimental Study of Velocity-Saturation Relationships in Volcanic Rocks

Liu¹,

Zhao²

2015

TOPEJ

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“…The model in this case is based on the volume of clay and saturation derived from the petrophysics and the total porosity derived from the density. The derivation of model involved mixing of minerals and pore space, then the fluids and finally the fluid mixture is introduced into the porous mineral mix via Gassmann's equations (Batzle and Wang 1992;Mavko and Mukerji 1995;Mavko et al 1998;Berryman 1999;Han and Batzle 2004). The modeling started under the assumption that the measured data are representative of invaded formation.…”

Section: Rock Physics Modelingmentioning

confidence: 99%

Petrophysical evaluation of well log data and rock physics modeling for characterization of Eocene reservoir in Chandmari oil field of Assam-Arakan basin, India

Kumar

Dasgupta

Singha

et al. 2017

J Petrol Explor Prod Technol

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Petrophysical evaluation of well log data has always been crucial for identification and assessment of hydrocarbon bearing zones. In present paper, petrophysical evaluation of well log data from cluster of six wells in the study area is carried out in combination with rock physics modeling for qualitative and quantitative characterization of Eocene reservoir in Chandmari oil field of Assam-Arakan basin, India. Petrophysical evaluation has provided the estimation of fluid and mineral types, rock/pore fabric type and fluid and mineral volumes for invaded and virgin zones. Calibrations are made where core data were available. Rock physics study is carried out for analyzing the influence of porosity, mineral compositions and saturation variations on the elastic properties of the subsurface. The rock physics modeling allowed quantitative prediction of relationship between porosity, saturation (gas, oil and water), clay volume and the elastic properties. Cross-plots of different elastic parameters are generated to identify the lithology variability and pore-fluid type, and to establish likely distinction between the hydrocarbon bearing sands, brine sands and shale. The Eocene reservoirs are found to be primarily sandstone intermixed with incidental clay matrix and some calcareous cementation. Sands are interpreted to be continuous in most of the blocks. The effective porosity for these sands varies from 15 to 22% in most of the wells. A wide range of variation is observed in water saturation with lowest being 5%. Finally, a numerical rock physics model is prepared to predict the elastic properties of the rock from petrophysical properties.

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“…Several fluid substitution studies (Han and Batzle, 2004;Simm, 2007;Khatiwada et al, 2012) have Gassmann's (1951) fluid substitution equations to estimate P-(V p ) and S-wave velocity (V s ) changes with increasing CO 2 saturation. V p and V s logs are needed to use Gassmann's fluid substitution.…”

Section: Arches Sims Final Technical Report 61mentioning

confidence: 99%

SIMULATION FRAMEWORK FOR REGIONAL GEOLOGIC CO{sub 2} STORAGE ALONG ARCHES PROVINCE OF MIDWESTERN UNITED STATES

Sminchak¹

2012

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This report presents final technical results for the project Simulation Framework for Regional Geologic CO 2 Storage Infrastructure along Arches Province of the Midwest UnitedStates. The Arches Simulation project was a three year effort designed to develop a simulation framework for regional geologic carbon dioxide (CO 2 ) storage infrastructure along the Arches Province through development of a geologic model and advanced reservoir simulations of large-scale CO 2 storage. The project included five major technical tasks: (1) compilation of geologic, hydraulic and injection data on Mount Simon, (2) development of model framework and parameters, (3) preliminary variable density flow simulations, (4) multi-phase model runs of regional storage scenarios, and (5) implications for regional storage feasibility. The Arches Province is an informal region in northeastern Indiana, northern Kentucky, western Ohio, and southern Michigan where sedimentary rock formations form broad arch and platform structures. In the province, the Mount Simon sandstone is an appealing deep saline formation for CO 2 storage because of the intersection of reservoir thickness and permeability. Many CO 2 sources are located in proximity to the Arches Province, and the area is adjacent to coal fired power plants along the Ohio River Valley corridor.Geophysical well logs, rock samples, drilling logs, and geotechnical tests were evaluated for a 500,000 km 2 study area centered on the Arches Province. Hydraulic parameters and historical operational information was also compiled from Mount Simon wastewater injection wells in the region. This information was integrated into a geocellular model that depicts the parameters and conditions in a numerical array. The geologic and hydraulic data were integrated into a three-dimensional grid of porosity and permeability, which are key parameters regarding fluid flow and pressure buildup due to CO 2 injection. Permeability data were corrected in locations where reservoir tests have been performed in Mount Simon injection wells.The geocellular model was used to develop a series of numerical simulations designed to support CO 2 storage applications in the Arches Province. Variable density fluid flow simulations were initially run to evaluate model sensitivity to input parameters. Two dimensional, multiple-phase simulations were completed to evaluate issues related to arranging injection fields in the study area. A basin-scale, multiple-phase model was developed to evaluate large scale injection effects across the region. Finally, local scale simulations were also completed with more detailed depiction of the Eau Claire formation to investigate to the potential for upward migration of CO 2 .Overall, the technical work on the project concluded that injection large-scale injection may be achieved with proper field design, operation, siting, and monitoring. Records from Mount Simon injection wells were compiled, documenting more than 20 billion gallons of injection into the Mount Simon formation in the Arch...

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Gassmann's equation and fluid‐saturation effects on seismic velocities

Cited by 222 publications

References 17 publications

An Experimental Study of Velocity-Saturation Relationships in Volcanic Rocks

An Experimental Study of Velocity-Saturation Relationships in Volcanic Rocks

Petrophysical evaluation of well log data and rock physics modeling for characterization of Eocene reservoir in Chandmari oil field of Assam-Arakan basin, India

SIMULATION FRAMEWORK FOR REGIONAL GEOLOGIC CO{sub 2} STORAGE ALONG ARCHES PROVINCE OF MIDWESTERN UNITED STATES

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