The coupling of dynamics and permeability in the hydrocarbon accumulation period controls the oil-bearing potential of low permeability reservoirs: a case study of the low permeability turbidite reservoirs in the middle part of the third member of Shahejie Formation in Dongying Sag

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The coupling of dynamics and permeability in the hydrocarbon accumulation period controls the oil-bearing potential of low permeability reservoirs: a case study of the low permeability turbidite reservoirs in the middle part of the third member of Shahejie Formation in Dongying Sag. / Yang, Tian; Cao, Ying-Chang; Wang, Yan-Zhong; Friis, Henrik; Haile, Beyene Girma ; Xi, Ke-Lai; Zhang, Hu-Na .

In: Petroleum Science, Vol. 13, No. 2, 05.2016, p. 204-224.

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@article{c4e055358cf54db6b7f3e474c8dfb678,
title = "The coupling of dynamics and permeability in the hydrocarbon accumulation period controls the oil-bearing potential of low permeability reservoirs: a case study of the low permeability turbidite reservoirs in the middle part of the third member of Shahejie Formation in Dongying Sag",
abstract = "The relationships between permeability and dynamics in hydrocarbon accumulation determine oilbearing potential (the potential oil charge) of low permeability reservoirs. The evolution of porosity and permeability of low permeability turbidite reservoirs of the middle part of the third member of the Shahejie Formation in the Dongying Sag has been investigated by detailed core descriptions, thin section analyses, fluid inclusion analyses, carbon and oxygen isotope analyses, mercury injection, porosity and permeability testing, and basin modeling. The cutoff values for the permeability of the reservoirs in the accumulation period were calculated after detailing the accumulation dynamics and reservoir pore structures, then the distribution pattern of the oil-bearing potential of reservoirs controlled by the matching relationship between dynamics and permeability during the accumulation period were summarized. On the basis of the observed diagenetic features and with regard to the paragenetic sequences, the reservoirs can be subdivided into four types of diagenetic facies. The reservoirs experienced two periods of hydrocarbon accumulation. In the early accumulation period, the reservoirs except for diagenetic facies A had middle to high permeability ranging from 10×10¯³μm2 to 4207.3×10¯³μm2. In the later accumulation period, the reservoirs except for diagenetic facies C had low permeability ranging from 0.015×10¯³μm2 to 62×10¯³μm2. In the early accumulation period, the fluid pressure increased by the hydrocarbon generation was 1.4–11.3 MPa with an average value of 5.1 MPa, and a surplus pressure of1.8–12.6 MPa with an average value of 6.3 MPa. In the later accumulation period, the fluid pressure increased by the hydrocarbon generation process was 0.7–12.7 MPa with an average value of 5.36 MPa and a surplus pressure of 1.3–16.2 MPa with an average value of 6.5 MPa. Even though different types of reservoirs exist, all can form hydrocarbon accumulations in the early accumulation period. Such types of reservoirs can form hydrocarbon accumulation with high accumulation dynamics; however, reservoirs with diagenetic facies A and diagenetic facies B do not develop accumulation conditions with low accumulation dynamics in the late accumulation period for very low permeability. At more than 3000 m burial depth, a larger proportion of turbidite reservoirs are oil charged due to the proximity to the source rock. Also at these depths, lenticular sand bodies can accumulate hydrocarbons. At shallower depths, only the reservoirs with oil-source fault development can accumulate hydrocarbons. For flat surfaces, hydrocarbons have always been accumulated in the reservoirs around the oil-source faults and areas near the center of subsags with high accumulation dynamics.",
keywords = "Reservoir porosity and permeability evolution, Accumulation dynamics, Cutoff-values of permeability in the accumulation period, Oil-bearing potential, Low permeability reservoir , The third member of the Shahejie Formation, Dongying Sag",
author = "Tian Yang and Ying-Chang Cao and Yan-Zhong Wang and Henrik Friis and Haile, {Beyene Girma} and Ke-Lai Xi and Hu-Na Zhang",
year = "2016",
month = "5",
doi = "10.1007/s12182-016-0099-0",
language = "English",
volume = "13",
pages = "204--224",
journal = "Petroleum Science",
issn = "1672-5107",
publisher = "Springer",
number = "2",

}

RIS

TY - JOUR

T1 - The coupling of dynamics and permeability in the hydrocarbon accumulation period controls the oil-bearing potential of low permeability reservoirs: a case study of the low permeability turbidite reservoirs in the middle part of the third member of Shahejie Formation in Dongying Sag

AU - Yang, Tian

AU - Cao, Ying-Chang

AU - Wang, Yan-Zhong

AU - Friis, Henrik

AU - Haile, Beyene Girma

AU - Xi, Ke-Lai

AU - Zhang, Hu-Na

PY - 2016/5

Y1 - 2016/5

N2 - The relationships between permeability and dynamics in hydrocarbon accumulation determine oilbearing potential (the potential oil charge) of low permeability reservoirs. The evolution of porosity and permeability of low permeability turbidite reservoirs of the middle part of the third member of the Shahejie Formation in the Dongying Sag has been investigated by detailed core descriptions, thin section analyses, fluid inclusion analyses, carbon and oxygen isotope analyses, mercury injection, porosity and permeability testing, and basin modeling. The cutoff values for the permeability of the reservoirs in the accumulation period were calculated after detailing the accumulation dynamics and reservoir pore structures, then the distribution pattern of the oil-bearing potential of reservoirs controlled by the matching relationship between dynamics and permeability during the accumulation period were summarized. On the basis of the observed diagenetic features and with regard to the paragenetic sequences, the reservoirs can be subdivided into four types of diagenetic facies. The reservoirs experienced two periods of hydrocarbon accumulation. In the early accumulation period, the reservoirs except for diagenetic facies A had middle to high permeability ranging from 10×10¯³μm2 to 4207.3×10¯³μm2. In the later accumulation period, the reservoirs except for diagenetic facies C had low permeability ranging from 0.015×10¯³μm2 to 62×10¯³μm2. In the early accumulation period, the fluid pressure increased by the hydrocarbon generation was 1.4–11.3 MPa with an average value of 5.1 MPa, and a surplus pressure of1.8–12.6 MPa with an average value of 6.3 MPa. In the later accumulation period, the fluid pressure increased by the hydrocarbon generation process was 0.7–12.7 MPa with an average value of 5.36 MPa and a surplus pressure of 1.3–16.2 MPa with an average value of 6.5 MPa. Even though different types of reservoirs exist, all can form hydrocarbon accumulations in the early accumulation period. Such types of reservoirs can form hydrocarbon accumulation with high accumulation dynamics; however, reservoirs with diagenetic facies A and diagenetic facies B do not develop accumulation conditions with low accumulation dynamics in the late accumulation period for very low permeability. At more than 3000 m burial depth, a larger proportion of turbidite reservoirs are oil charged due to the proximity to the source rock. Also at these depths, lenticular sand bodies can accumulate hydrocarbons. At shallower depths, only the reservoirs with oil-source fault development can accumulate hydrocarbons. For flat surfaces, hydrocarbons have always been accumulated in the reservoirs around the oil-source faults and areas near the center of subsags with high accumulation dynamics.

AB - The relationships between permeability and dynamics in hydrocarbon accumulation determine oilbearing potential (the potential oil charge) of low permeability reservoirs. The evolution of porosity and permeability of low permeability turbidite reservoirs of the middle part of the third member of the Shahejie Formation in the Dongying Sag has been investigated by detailed core descriptions, thin section analyses, fluid inclusion analyses, carbon and oxygen isotope analyses, mercury injection, porosity and permeability testing, and basin modeling. The cutoff values for the permeability of the reservoirs in the accumulation period were calculated after detailing the accumulation dynamics and reservoir pore structures, then the distribution pattern of the oil-bearing potential of reservoirs controlled by the matching relationship between dynamics and permeability during the accumulation period were summarized. On the basis of the observed diagenetic features and with regard to the paragenetic sequences, the reservoirs can be subdivided into four types of diagenetic facies. The reservoirs experienced two periods of hydrocarbon accumulation. In the early accumulation period, the reservoirs except for diagenetic facies A had middle to high permeability ranging from 10×10¯³μm2 to 4207.3×10¯³μm2. In the later accumulation period, the reservoirs except for diagenetic facies C had low permeability ranging from 0.015×10¯³μm2 to 62×10¯³μm2. In the early accumulation period, the fluid pressure increased by the hydrocarbon generation was 1.4–11.3 MPa with an average value of 5.1 MPa, and a surplus pressure of1.8–12.6 MPa with an average value of 6.3 MPa. In the later accumulation period, the fluid pressure increased by the hydrocarbon generation process was 0.7–12.7 MPa with an average value of 5.36 MPa and a surplus pressure of 1.3–16.2 MPa with an average value of 6.5 MPa. Even though different types of reservoirs exist, all can form hydrocarbon accumulations in the early accumulation period. Such types of reservoirs can form hydrocarbon accumulation with high accumulation dynamics; however, reservoirs with diagenetic facies A and diagenetic facies B do not develop accumulation conditions with low accumulation dynamics in the late accumulation period for very low permeability. At more than 3000 m burial depth, a larger proportion of turbidite reservoirs are oil charged due to the proximity to the source rock. Also at these depths, lenticular sand bodies can accumulate hydrocarbons. At shallower depths, only the reservoirs with oil-source fault development can accumulate hydrocarbons. For flat surfaces, hydrocarbons have always been accumulated in the reservoirs around the oil-source faults and areas near the center of subsags with high accumulation dynamics.

KW - Reservoir porosity and permeability evolution

KW - Accumulation dynamics

KW - Cutoff-values of permeability in the accumulation period

KW - Oil-bearing potential

KW - Low permeability reservoir

KW - The third member of the Shahejie Formation

KW - Dongying Sag

U2 - 10.1007/s12182-016-0099-0

DO - 10.1007/s12182-016-0099-0

M3 - Journal article

VL - 13

SP - 204

EP - 224

JO - Petroleum Science

JF - Petroleum Science

SN - 1672-5107

IS - 2

ER -