Biot–Gassmann theory for velocities of gas hydrate‐bearing sediments

Lee, Myung W.

doi:10.1190/1.1527072

Cited by 145 publications

(138 citation statements)

References 20 publications

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“…Contrary to Gassmann's (1951) assumption, Lee (2002) showed that the shear modulus also exhibits a dependence on the rock's water saturation, w S , and proposed the following formula for the shear modulus of a fluid-saturated rock: 222 * 2…”

Section: B32 Relation Between Rock Physics and Petrophysical Promentioning

confidence: 99%

“…In determining the relationship between elastic moduli with porosity and saturation we use Lee's (2002) extension of the Biot-Gassmann model. With the sensitivity study we observe that the sensitivity of porosity to the seismic velocities (both P-and S) is considerable while that of the saturation is insignificant.…”

Section: B36 Conclusionmentioning

confidence: 99%

“…(3.B.13) Lee (2002) proposed the following empirical relation to compute Biot's coefficient and showed that β asymptotically approaches the value of one with an increase in the rock's porosity: …”

Section: B31 Introductionmentioning

confidence: 99%

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Integrated Approach for the Petrophysical Interpretation of Post- And Pre-Stack 3-D Seismic Data, Well-Log Data, Core Data, Geological Information and Reservoir Production Data via Bayesian Stochastic Inversion

Torres‐Verdín¹,

Sen²

2004

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During the third year of work for this project we focused primarily on improving the efficiency of inversion algorithms and on developing algorithms for direct estimation of petrophysical parameters. The full waveform inversion algorithm for elastic property estimation was tested rigorously on a personal computer cluster. For sixteen nodes on the cluster the parallel algorithm was found to be scalable with a near linear speedup. This enabled us to invert a 2D seismic line in less than five hours of CPU time. We were invited to write a paper on our results that was subsequently accepted for publication. We also carried out a rigorous study to examine the sensitivity and resolution of seismic data to petrophysical parameters. In other words, we developed a full waveform inversion algorithm that estimates petrophysical parameters such as porosity and saturation from pre-stack seismic waveform data. First we used a modified Biot-Gassmann equation to relate petrophysical parameters to elastic parameters. The transformation was validated with a suite of well logs acquired in the deepwater Gulf of Mexico. As a part of this study, we carried out a sensitivity analysis and found that the porosity is very well resolved while the fluid saturation remains insensitive to seismic wave amplitudes. Finally we conducted a joint inversion of pre-stack seismic waveform and production history data. To overcome the computational difficulties we used a simpler waveform modeling algorithm together with an efficient subspace approach. The algorithm was tested on a realistic synthetic data set. We observed that the use of pre-stack seismic data helps tremendously to improve horizontal resolution of porosity maps. Finally, we submitted four publications to refereed technical journals, two ~iv~ refereed extended abstracts to technical conferences, and delivered two oral presentation at a technical forum. All of these publications and presentations stemmed from work directly related to the goals of our DOE project.

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Section: B32 Relation Between Rock Physics and Petrophysical Promentioning

confidence: 99%

Section: B36 Conclusionmentioning

confidence: 99%

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Integrated Approach for the Petrophysical Interpretation of Post- And Pre-Stack 3-D Seismic Data, Well-Log Data, Core Data, Geological Information and Reservoir Production Data via Bayesian Stochastic Inversion

Torres‐Verdín¹,

Sen²

2004

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“…The exponent m is a function of porosity Φ (Goldberg and Gurevich 1998;Lee 2002). The parameter M can be obtained from the relation: , (2.11)…”

Section: Modified Biot-gassmann Modelmentioning

confidence: 99%

Evaluation of Non-Nuclear Techniques for Well Logging: Technology Evaluation

Bond¹,

Denslow²,

Griffin³

et al. 2010

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Sealed, chemical isotope radiation sources have a diverse range of industrial applications. There is concern that such sources currently used in the gas/oil well logging industry (e.g., americium-beryllium [AmBe], 252 Cf, 60 Co, and 137 Cs) can potentially be diverted and used in dirty bombs. Recent actions by the U.S. Department of Energy (DOE) have reduced the availability of these sources in the United States. Alternatives, both radiological and non-radiological methods, are actively being sought within the oilfield services community. The use of isotopic sources can potentially be further reduced, and source use reduction made more acceptable to the user community, if suitable non-nuclear or non-isotope-based well logging techniques can be developed. Data acquired with these non-nuclear techniques must be demonstrated to correlate with that acquired using isotope sources and historic records. To enable isotopic source reduction there is a need to assess technologies to determine (i) if it is technically feasible to replace isotopic sources with alternate sensing technologies and (ii) to provide independent technical data to guide DOE (and the Nuclear Regulatory Commission [NRC]) on issues relating to replacement and/or reduction of radioactive sources used in well logging.This report presents an initial review of the state-of-the-art nuclear and non-nuclear well logging methods and seeks to understand the technical and economic issues if AmBe, and potentially other isotope sources, are reduced or even eliminated in the oil-field services industry. Prior to considering alternative logging technologies, there is a definite need to open up discussions with industry regarding the feasibility and acceptability of source replacement. Industry views appear to range from those who see AmBe as vital and irreplaceable to those who believe that, with research and investment, it may be possible -to transition to electronic neutron sources and employ combinations of non-nuclear technologies to acquire the desired petro-physical parameters. In one sense, the simple answer to the question as to whether petro-physical parameters can be sensed with technologies other than AmBe is probably "Yes". The challenges come when attention turns to record interpretation. The many decades of existing records form a very valuable proprietary resource, and the interpretation of subtle features contained in these records are of significant value to the oil-gas exploration community to correctly characterize a well. The demonstration of equivalence and correspondence/correlation between established and any new sensing modality, and correlations with historic records is critical to ensuring accurate data interpretation. Establishing the technical basis for such a demonstration represents a significant effort.The focus of this study is the understanding of the technical obstacles that hinder the replacement of and the disadvantages from the loss of extensive interpretation experience based on data accumulated with AmBe. Enhanced ac...

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“…Two different approaches were used to relate the hydrate saturation and velocity in oceanic sediments: (1) empirical methods including Wyllie's time average [Wyllie et al, 1958;Pearson et al, 1983], Wood's equation [Wood, 1941] and weighted combinations of the Wyllie's time average and Wood's equation [Lee et al, 1996], and (2) physics-based models, such as the effective medium theory (EMT) [Helgerud et al, 1999;Dvorkin and Prasad, 1999] and the Biot-Gassmann theory modified by Lee (BGTL) [Lee, 2002a[Lee, , 2002b[Lee, , 2003]. However, the gas hydrate volumes within sediments estimated with these approaches are quite different.…”

Section: Introductionmentioning

confidence: 99%