Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes

Chang Deshuang; Chen Zhigang; Han Yuchun; Sun Xing; Chen Jie; Zhao Qian; Zhao Xiaoqing

doi:doi:10.11648/j.ogce.20210903.11

| Peer-Reviewed

Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes

Chang Deshuang, Chen Zhigang, Han Yuchun, Sun Xing, Chen Jie, Zhao Qian, Zhao Xiaoqing

Published in International Journal of Oil, Gas and Coal Engineering (Volume 9, Issue 3)

Received: 27 April 2021 Accepted: 10 May 2021 Published: 22 July 2021

Views: Downloads:

Download PDF

Share This Article

Twitter
Linked In
Facebook

Abstract

In the same hydrodynamic system, because the densities of oil and gas are smaller than that of water, their pressure gradients are also smaller. Therefore, the pressure gradient can determine fluid properties. Based on seismic data and well logging data, this paper attempts to apply the equivalent medium theory to predict the pressure gradient, and then to identify fluids. Firstly, the upper and lower limits of bulk modulus and shear modulus of rocks can be obtained by using wellbore and well logging interpretation data. Secondly, based on the equivalent medium theory, the fluid velocity (when rock rigidity approaching zero) and the rock matrix velocity (when porosity approaching zero) are predicted. Thirdly, the predicted two types of velocity curves and the original acoustic curves are used for seismic inversion. Finally, according to the inversion results, the formation pressure and pressure gradient can be obtained by using the Fillippone pressure formula, and the hydrocarbon-bearing property of reservoirs can be determined according to the theoretical pressure gradients of different fluids. For offshore deep-water sandstone in an overseas block, when the frequency attributes for hydrocarbon detection cannot reflect hydrocarbons well, the fluid pressure gradient attribute is used to predict hydrocarbons, and the prediction coincidence rate reaches 70%.

Published in	International Journal of Oil, Gas and Coal Engineering (Volume 9, Issue 3)
DOI	10.11648/j.ogce.20210903.11
Page(s)	36-41
Creative Commons	This is an Open Access article, distributed under the terms of the Creative Commons Attribution 4.0 International License (http://creativecommons.org/licenses/by/4.0/), which permits unrestricted use, distribution and reproduction in any medium or format, provided the original work is properly cited.
Copyright	Copyright © The Author(s), 2024. Published by Science Publishing Group

Keywords

Pressure Gradient, Bulk Modulus, Shear Modulus, Hydrocarbon Detection, Equivalent Medium Theory

References

[1]	LANG X L, PENG S M, KANG H Q, et al. Application of prestack simultaneous inversion in fluid identification [J]. Geophysical Prospecting for Petroleum, 2010, 49 (2): 164-169.
[2]	HUANG R, LIU Z B. Application of prestack simultaneous inversion in sandstone oil reservoir prediction [J]. Progress in Geophysics, 2013, 28 (1): 380-386.
[3]	GAO Y, ZHU Y K, ZHAO H, et al. Application of prestack simultaneous inversion technique in effective reservoir prediction of sand-gravel body [J]. Geophysical Prospecting for Petroleum, 2013, 52 (2): 223-228.
[4]	XIE Y L. Application study of 3D hydrocarbon detection technology in Fenggu area in western Sichuan basin [J]. Natural Gas Industry, 2006, 26 (3): 46-49.
[5]	ZHAO W J, YANG W Y, ZHANG Q F, et al. A frequency AVO method for hydrocarbon detection. [J]. Oil Geophysical Prospecting, 2012, 47 (3): 436-441.
[6]	ZHANG Z W, HE Z H, TANG X R. Prediction of reef facies reservoirs based on low-frequency shadow and waveimpedance inversion [J]. Geophysical Prospecting for Petroleum, 2010, 49 (6): 611-615.
[7]	LIU W, HE Z H, CHEN X H, et al. Detection of Oil and Gas in Turbidite Fan System by Low-Frequency Shadows Method [J]. Xinjiang Petroleum Geology, 2011 (6): 609-612.
[8]	WANG X P, HE Z H, XIONG X J. Namerical simulation of low frequency adjoint-shadows based on wavelet attenuation and hydrocarbon detection [J]. Petroleum Geology and Oilfield Development in Daqing, 2011, 30 (1): 157-160.
[9]	GEERTSMA J, SMIT D C. Some aspects of elastic wave propagation in fluid-saturated porous solids [J]. Geophysics, 1961, 26: 169-181.
[10]	THEODOROS K, CLIVE M C. Why is the Biot’s low compressional wave not observed in real rocks? [J]. Geophysics, 1988, 53: 1605-1609.
[11]	LIANG X W, SHI X H, CAI F X, at al. A multi-phase theory based hydrocarbon detection method [J]. Oil Geophysical Prospecting, 2002, 25 (6): 32-35.
[12]	ZHANG Y B. Biot theory in application to seismic prospecting [J]. Geophysical Prospecting for Petroleum, 1994, 33 (4): 29-38.
[13]	FILLIPPONE W R. Estimation of formation parameters and the prediction of overpressures from seismic data [R]. SEG Technical Program Expanded Abstracts, 1982 (1): 502-503.
[14]	RUBEN D, MARTINEZ. Deterministic estimation of porosity and formation pressure from seismic data [R]. SEG Technical Program Expanded Abstracts, 1999: 461-464.
[15]	LIU Z, ZHANG W X, ZHANG H F, at al. An analysis of abnormal formation pressures of Paleogene in the north sag of Liaoxi depression [J]. University of Petroleum, 1993, 14 (1): 14-24.
[16]	YUN M H. Formation pressure prediction using seismic data [J]. Oil Geophysical Prospecting, 1996, 31 (4): 5 75-586.
[17]	Qian L P, Wang X, Li F, et al. Formation pore pressure prediction using Fillipone formula combined with the equivalent medium theory [J]. Oil Geophysical Prospection, 2018, 53 (Sup. 2): 224-229.
[18]	VOIGT W. Ueber die Beziehung Zwischen den beiden Elastizitatsconstanten isotroper Korper [J]. Annalen Der Physi, 1889, 274 (12): 573-587.
[19]	REUSS A, A NGEW Z. Berechnung del fliessgrenze von misch- kristallen auf grund der plastizitatbedingung for einkristalle [J]. Math Mech, 1929, 9 (1): 49-58.

Cite This Article

Plain Text BibTeX RIS

APA Style

Chang Deshuang, Chen Zhigang, Han Yuchun, Sun Xing, Chen Jie, et al. (2021). Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes. International Journal of Oil, Gas and Coal Engineering, 9(3), 36-41. https://doi.org/10.11648/j.ogce.20210903.11

Copy | Download

ACS Style

Chang Deshuang; Chen Zhigang; Han Yuchun; Sun Xing; Chen Jie, et al. Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes. Int. J. Oil Gas Coal Eng. 2021, 9(3), 36-41. doi: 10.11648/j.ogce.20210903.11

Copy | Download

AMA Style

Chang Deshuang, Chen Zhigang, Han Yuchun, Sun Xing, Chen Jie, et al. Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes. Int J Oil Gas Coal Eng. 2021;9(3):36-41. doi: 10.11648/j.ogce.20210903.11

Copy | Download

@article{10.11648/j.ogce.20210903.11,
  author = {Chang Deshuang and Chen Zhigang and Han Yuchun and Sun Xing and Chen Jie and Zhao Qian and Zhao Xiaoqing},
  title = {Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes},
  journal = {International Journal of Oil, Gas and Coal Engineering},
  volume = {9},
  number = {3},
  pages = {36-41},
  doi = {10.11648/j.ogce.20210903.11},
  url = {https://doi.org/10.11648/j.ogce.20210903.11},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ogce.20210903.11},
  abstract = {In the same hydrodynamic system, because the densities of oil and gas are smaller than that of water, their pressure gradients are also smaller. Therefore, the pressure gradient can determine fluid properties. Based on seismic data and well logging data, this paper attempts to apply the equivalent medium theory to predict the pressure gradient, and then to identify fluids. Firstly, the upper and lower limits of bulk modulus and shear modulus of rocks can be obtained by using wellbore and well logging interpretation data. Secondly, based on the equivalent medium theory, the fluid velocity (when rock rigidity approaching zero) and the rock matrix velocity (when porosity approaching zero) are predicted. Thirdly, the predicted two types of velocity curves and the original acoustic curves are used for seismic inversion. Finally, according to the inversion results, the formation pressure and pressure gradient can be obtained by using the Fillippone pressure formula, and the hydrocarbon-bearing property of reservoirs can be determined according to the theoretical pressure gradients of different fluids. For offshore deep-water sandstone in an overseas block, when the frequency attributes for hydrocarbon detection cannot reflect hydrocarbons well, the fluid pressure gradient attribute is used to predict hydrocarbons, and the prediction coincidence rate reaches 70%.},
 year = {2021}
}

Copy | Download

TY  - JOUR
T1  - Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes
AU  - Chang Deshuang
AU  - Chen Zhigang
AU  - Han Yuchun
AU  - Sun Xing
AU  - Chen Jie
AU  - Zhao Qian
AU  - Zhao Xiaoqing
Y1  - 2021/07/22
PY  - 2021
N1  - https://doi.org/10.11648/j.ogce.20210903.11
DO  - 10.11648/j.ogce.20210903.11
T2  - International Journal of Oil, Gas and Coal Engineering
JF  - International Journal of Oil, Gas and Coal Engineering
JO  - International Journal of Oil, Gas and Coal Engineering
SP  - 36
EP  - 41
PB  - Science Publishing Group
SN  - 2376-7677
UR  - https://doi.org/10.11648/j.ogce.20210903.11
AB  - In the same hydrodynamic system, because the densities of oil and gas are smaller than that of water, their pressure gradients are also smaller. Therefore, the pressure gradient can determine fluid properties. Based on seismic data and well logging data, this paper attempts to apply the equivalent medium theory to predict the pressure gradient, and then to identify fluids. Firstly, the upper and lower limits of bulk modulus and shear modulus of rocks can be obtained by using wellbore and well logging interpretation data. Secondly, based on the equivalent medium theory, the fluid velocity (when rock rigidity approaching zero) and the rock matrix velocity (when porosity approaching zero) are predicted. Thirdly, the predicted two types of velocity curves and the original acoustic curves are used for seismic inversion. Finally, according to the inversion results, the formation pressure and pressure gradient can be obtained by using the Fillippone pressure formula, and the hydrocarbon-bearing property of reservoirs can be determined according to the theoretical pressure gradients of different fluids. For offshore deep-water sandstone in an overseas block, when the frequency attributes for hydrocarbon detection cannot reflect hydrocarbons well, the fluid pressure gradient attribute is used to predict hydrocarbons, and the prediction coincidence rate reaches 70%.
VL  - 9
IS  - 3
ER  -

Copy | Download

Author Information

Chang Deshuang

Geological Research Center, Bureau of Geophysical Prospect, Zhuozhou, China
Chen Zhigang

Geological Research Center, Bureau of Geophysical Prospect, Zhuozhou, China
Han Yuchun

Geological Research Center, Bureau of Geophysical Prospect, Zhuozhou, China
Sun Xing

Geological Research Center, Bureau of Geophysical Prospect, Zhuozhou, China
Chen Jie

Geological Research Center, Bureau of Geophysical Prospect, Zhuozhou, China
Zhao Qian

Geological Research Center, Bureau of Geophysical Prospect, Zhuozhou, China
Zhao Xiaoqing

Geological Research Center, Bureau of Geophysical Prospect, Zhuozhou, China

Download PDF

Sections

Plain Text BibTeX RIS

APA Style

Chang Deshuang, Chen Zhigang, Han Yuchun, Sun Xing, Chen Jie, et al. (2021). Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes. International Journal of Oil, Gas and Coal Engineering, 9(3), 36-41. https://doi.org/10.11648/j.ogce.20210903.11

Copy | Download

ACS Style

Chang Deshuang; Chen Zhigang; Han Yuchun; Sun Xing; Chen Jie, et al. Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes. Int. J. Oil Gas Coal Eng. 2021, 9(3), 36-41. doi: 10.11648/j.ogce.20210903.11

Copy | Download

AMA Style

Chang Deshuang, Chen Zhigang, Han Yuchun, Sun Xing, Chen Jie, et al. Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes. Int J Oil Gas Coal Eng. 2021;9(3):36-41. doi: 10.11648/j.ogce.20210903.11

Copy | Download

@article{10.11648/j.ogce.20210903.11,
  author = {Chang Deshuang and Chen Zhigang and Han Yuchun and Sun Xing and Chen Jie and Zhao Qian and Zhao Xiaoqing},
  title = {Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes},
  journal = {International Journal of Oil, Gas and Coal Engineering},
  volume = {9},
  number = {3},
  pages = {36-41},
  doi = {10.11648/j.ogce.20210903.11},
  url = {https://doi.org/10.11648/j.ogce.20210903.11},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ogce.20210903.11},
  abstract = {In the same hydrodynamic system, because the densities of oil and gas are smaller than that of water, their pressure gradients are also smaller. Therefore, the pressure gradient can determine fluid properties. Based on seismic data and well logging data, this paper attempts to apply the equivalent medium theory to predict the pressure gradient, and then to identify fluids. Firstly, the upper and lower limits of bulk modulus and shear modulus of rocks can be obtained by using wellbore and well logging interpretation data. Secondly, based on the equivalent medium theory, the fluid velocity (when rock rigidity approaching zero) and the rock matrix velocity (when porosity approaching zero) are predicted. Thirdly, the predicted two types of velocity curves and the original acoustic curves are used for seismic inversion. Finally, according to the inversion results, the formation pressure and pressure gradient can be obtained by using the Fillippone pressure formula, and the hydrocarbon-bearing property of reservoirs can be determined according to the theoretical pressure gradients of different fluids. For offshore deep-water sandstone in an overseas block, when the frequency attributes for hydrocarbon detection cannot reflect hydrocarbons well, the fluid pressure gradient attribute is used to predict hydrocarbons, and the prediction coincidence rate reaches 70%.},
 year = {2021}
}

Copy | Download

TY  - JOUR
T1  - Determination of Hydrocarbon-bearing Property of Deep-water Sandstone by Fluid Pressure Gradient from Seismic Attributes
AU  - Chang Deshuang
AU  - Chen Zhigang
AU  - Han Yuchun
AU  - Sun Xing
AU  - Chen Jie
AU  - Zhao Qian
AU  - Zhao Xiaoqing
Y1  - 2021/07/22
PY  - 2021
N1  - https://doi.org/10.11648/j.ogce.20210903.11
DO  - 10.11648/j.ogce.20210903.11
T2  - International Journal of Oil, Gas and Coal Engineering
JF  - International Journal of Oil, Gas and Coal Engineering
JO  - International Journal of Oil, Gas and Coal Engineering
SP  - 36
EP  - 41
PB  - Science Publishing Group
SN  - 2376-7677
UR  - https://doi.org/10.11648/j.ogce.20210903.11
AB  - In the same hydrodynamic system, because the densities of oil and gas are smaller than that of water, their pressure gradients are also smaller. Therefore, the pressure gradient can determine fluid properties. Based on seismic data and well logging data, this paper attempts to apply the equivalent medium theory to predict the pressure gradient, and then to identify fluids. Firstly, the upper and lower limits of bulk modulus and shear modulus of rocks can be obtained by using wellbore and well logging interpretation data. Secondly, based on the equivalent medium theory, the fluid velocity (when rock rigidity approaching zero) and the rock matrix velocity (when porosity approaching zero) are predicted. Thirdly, the predicted two types of velocity curves and the original acoustic curves are used for seismic inversion. Finally, according to the inversion results, the formation pressure and pressure gradient can be obtained by using the Fillippone pressure formula, and the hydrocarbon-bearing property of reservoirs can be determined according to the theoretical pressure gradients of different fluids. For offshore deep-water sandstone in an overseas block, when the frequency attributes for hydrocarbon detection cannot reflect hydrocarbons well, the fluid pressure gradient attribute is used to predict hydrocarbons, and the prediction coincidence rate reaches 70%.
VL  - 9
IS  - 3
ER  -

Copy | Download