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Bradley J. Huizinga - One of the best experts on this subject based on the ideXlab platform.

  • Genetic Classification of Petroleum Systems Using Three Factors: Charge, Migration, and Entrapment: Chapter 4: Part I. Introduction
    1994
    Co-Authors: Gerard J. Demaison, Bradley J. Huizinga
    Abstract:

    Our genetic classification of petroleum systems is founded on a simple working nomenclature that consists of combining qualifiers from each of the following three categories: (1) charge factor (supercharged, normally charged, or undercharged), (2) migration drainage style (vertically drained or laterally drained), and (3) entrapment style (high impedance or low impedance). The charge factor is estimated using the initial richness of the source rock and the volume of mature source rock. The source potential index (SPI), which combines source rock richness and net source rock thickness into a single parameter, is a convenient shortcut for comparing the petroleum potential of diverse source rocks containing dissimilar kerogen types and for rapidly estimating regional charging capacity. In extensively explored petroleum provinces that contain a single petroleum system, a positive correlation exists between the magnitude of the SPI and province-wide petroleum reserves. Migration drainage style is determined from the structural and stratigraphic framework of the basin fill. Vertical migration drainage, which occurs mainly through faults and fractures that breach a Seal, is characteristic of petroleum systems in rift basins, deltaic sequences, salt dome provinces, wrench basins, and fold and thrust belts. In contrast, lateral migration drainage is dominant wherever stratigraphically continuous Seal-Reservoir "doublets" or carrier beds extend over a large area in a tectonically stable province (e.g., foreland or intracratonic platform basins). Recognition of the dominant migration style helps to predict the location of zones of petroleum occurrence in relation to the pod of mature source rock. Entrapment style, which is also dependent on the structural framework and the presence and effectiveness of Seals, describes the degree of resistance (impedance) working against dispersion of the petroleum charge. Application of these working concepts should help to reduce geologic risk significantly, particularly in new ventures exploration.

  • Genetic classification of petroleum systems
    AAPG Bulletin, 1991
    Co-Authors: Gerard J. Demaison, Bradley J. Huizinga
    Abstract:

    Our genetic classification of petroleum systems is founded on a simple working nomenclature that consists of combining qualifiers from each of the following three categories: (1) charge factor (supercharged, normally charged, or undercharged), (2) migration drainage style (vertically drained or laterally drained), and (3) entrapment style (high impedance or low impedance). The charge factor is estimated on the basis of the richness and volumetrics of mature source rocks. The source potential index (SPI), which combines source-rock richness and thickness into a single parameter, is a convenient shortcut for comparing the petroleum potential of diverse source rocks containing dissimilar kerogen types and for rapidly estimating regional charging capacity. In extensively explored basins, a positive correlation exists between the magnitude of SPI and basin-wide petroleum reserves. The migration drainage style is determined from the structural and stratigraphic framework of a basin. Vertical-migration drainage, which occurs mainly through faults and fracture systems breaching a Seal, is characteristic of petroleum systems contained within rift basins, deltaic sequences, salt-dome provinces, wrench basins, and fold-and-thrust belts. In contrast, lateral-migration drainage is dominant wherever stratigraphically continuous Seal-Reservoir "doublets" extend over a very large area in a tectonically stable province (e.g., commonly foreland or intracratonic platform basins). Recognition of the dominant migration style helps to predict the location of zones of petroleum occurrence in relation to the "hydrocarbon kitchens." The entrapment style, which is also dependent on the structural framework and the presence and effectiveness of Seals, describes the degree of resistance (i.e., impedance) working against dispersion of the petroleum charge. Application of these working concepts should help to significantly reduce geologic risk, particularly in new ventures-type exploration.

Gerard J. Demaison - One of the best experts on this subject based on the ideXlab platform.

  • Genetic Classification of Petroleum Systems Using Three Factors: Charge, Migration, and Entrapment: Chapter 4: Part I. Introduction
    1994
    Co-Authors: Gerard J. Demaison, Bradley J. Huizinga
    Abstract:

    Our genetic classification of petroleum systems is founded on a simple working nomenclature that consists of combining qualifiers from each of the following three categories: (1) charge factor (supercharged, normally charged, or undercharged), (2) migration drainage style (vertically drained or laterally drained), and (3) entrapment style (high impedance or low impedance). The charge factor is estimated using the initial richness of the source rock and the volume of mature source rock. The source potential index (SPI), which combines source rock richness and net source rock thickness into a single parameter, is a convenient shortcut for comparing the petroleum potential of diverse source rocks containing dissimilar kerogen types and for rapidly estimating regional charging capacity. In extensively explored petroleum provinces that contain a single petroleum system, a positive correlation exists between the magnitude of the SPI and province-wide petroleum reserves. Migration drainage style is determined from the structural and stratigraphic framework of the basin fill. Vertical migration drainage, which occurs mainly through faults and fractures that breach a Seal, is characteristic of petroleum systems in rift basins, deltaic sequences, salt dome provinces, wrench basins, and fold and thrust belts. In contrast, lateral migration drainage is dominant wherever stratigraphically continuous Seal-Reservoir "doublets" or carrier beds extend over a large area in a tectonically stable province (e.g., foreland or intracratonic platform basins). Recognition of the dominant migration style helps to predict the location of zones of petroleum occurrence in relation to the pod of mature source rock. Entrapment style, which is also dependent on the structural framework and the presence and effectiveness of Seals, describes the degree of resistance (impedance) working against dispersion of the petroleum charge. Application of these working concepts should help to reduce geologic risk significantly, particularly in new ventures exploration.

  • Genetic classification of petroleum systems
    AAPG Bulletin, 1991
    Co-Authors: Gerard J. Demaison, Bradley J. Huizinga
    Abstract:

    Our genetic classification of petroleum systems is founded on a simple working nomenclature that consists of combining qualifiers from each of the following three categories: (1) charge factor (supercharged, normally charged, or undercharged), (2) migration drainage style (vertically drained or laterally drained), and (3) entrapment style (high impedance or low impedance). The charge factor is estimated on the basis of the richness and volumetrics of mature source rocks. The source potential index (SPI), which combines source-rock richness and thickness into a single parameter, is a convenient shortcut for comparing the petroleum potential of diverse source rocks containing dissimilar kerogen types and for rapidly estimating regional charging capacity. In extensively explored basins, a positive correlation exists between the magnitude of SPI and basin-wide petroleum reserves. The migration drainage style is determined from the structural and stratigraphic framework of a basin. Vertical-migration drainage, which occurs mainly through faults and fracture systems breaching a Seal, is characteristic of petroleum systems contained within rift basins, deltaic sequences, salt-dome provinces, wrench basins, and fold-and-thrust belts. In contrast, lateral-migration drainage is dominant wherever stratigraphically continuous Seal-Reservoir "doublets" extend over a very large area in a tectonically stable province (e.g., commonly foreland or intracratonic platform basins). Recognition of the dominant migration style helps to predict the location of zones of petroleum occurrence in relation to the "hydrocarbon kitchens." The entrapment style, which is also dependent on the structural framework and the presence and effectiveness of Seals, describes the degree of resistance (i.e., impedance) working against dispersion of the petroleum charge. Application of these working concepts should help to significantly reduce geologic risk, particularly in new ventures-type exploration.

Zheng Duo-ming - One of the best experts on this subject based on the ideXlab platform.

  • On Petroleum Geology of Luobupo Sag in Tarim Basin.
    Xinjiang Petroleum Geology, 2020
    Co-Authors: Zheng Duo-ming
    Abstract:

    Luobupo sag is located on east of Yingjisu sag.Both of sags are situated in eastern Tarim basin.Great success of petroleum exploration had been achieved in Yingjisu sag in2002.Based on the analyses of basinal type,tectonic evolution,trap development,source rock evaluation,Reservoir and Seal-Reservoir assemblages,we believe that Luobupo sag has the same geologic evolution history and basic petroleum geologic condition as Yingjisu sag.It is also of good prospect for making breakthrough of petroleum exploration.

Jie Zhou - One of the best experts on this subject based on the ideXlab platform.

  • Characteristics and differential accumulation of oil/gas in Lower Paleozoic marine carbonate on northern slope of Tazhong Low Rise, Tarim Basin, NW China: a case study of Lower Ordovician Yingshan Formation
    Arabian Journal of Geosciences, 2013
    Co-Authors: Xiuxiang Lü, Hongfeng Yu, Jie Zhou
    Abstract:

    Marine carbonate Reservoirs, as a focus of petroleum exploration and development all over the world, are involved with high exploration risk and prediction difficulty owing to high heterogeneity and diversity of Reservoir beds. In the Tarim Basin, NW China, carbonate Reservoirs with resources about 38 % of the whole basin in a large prospecting area are mainly distributed in the Cambrian and Ordovician in central (Tazhong) and northern (Tabei) Tarim. Recently on the northern slope, Tazhong Low Rise, Central Uplift, Tarim Basin, a breakthrough has been made in the karsted weathering crust of Lower Ordovician Yingshan Formation and reef-flat Reservoir of Upper Ordovician Lianglitag Formation. As a new frontier of exploration, oil/gas distribution and controlling factors of carbonate Reservoirs in the Yingshan Formation are not clearly understood. In this work, play elements of the Yingshan Formation, such as Seal-Reservoir bed assemblage, oil/gas properties, and faulting, were studied by core and slice observation and field investigation. High-quality Reservoir beds of Yingshan Formation are quasi-layer distributed in the interstratal karst belt about 250 m below the unconformity. The Reservoir beds of fracture–void and void are formed by faulting, associated fracturing, and karstification. The Yingshan Formation is a large-scale condensate gas Reservoir with partly oil. Owing to different oil–gas infilling periods, isolated pools far from the faults are primarily oil in the Hercynian; oppositely, condensate gas Reservoirs near the faults are intensely influenced by gas invasion during the Himalayan movement. Laterally, oil/gas distribution is controlled by stratal pinch-out and strike-slip faults. Vertically, cap rock of the third to fifth members of the Lianglitag Formation and Yingshan interior high resistivity layers are superimposed with Yingshan Reservoir beds to form several Seal-Reservoir bed assemblages. Oil and gas are superimposed and affected by gas invasion with characteristics of oil in the upper horizon and gas in the lower horizon.

H. Veldkamp - One of the best experts on this subject based on the ideXlab platform.

  • Identifying hidden risk elements for CO2 storage from reprocessed seismic data
    Fifth CO2 Geological Storage Workshop, 2018
    Co-Authors: S. Carpentier, H. Abidin, P. Steeghs, H. Veldkamp
    Abstract:

    CO2 storage needs economic business cases through cost-effective exploration and production and needs license-to-operate through public support. Re-interpretation and reprocessing of vintage geophysical data is a means to achieve cost-effective exploration whereas de-risking and conformance control of storage operations is a means to obtain public support. Seismic exploration should identify risk elements for CO2 storage such as the risk of leakage, risk of pressure build-ups or drops, unexpected increase or decrease of storage capacity and spill points to name a few. These risks elements are often caused by hidden features such as a failing overburden Seal, closed or open faults in either Reservoir or Seal and high- or low-permeability streaks in the Reservoir. We have investigated a seismic reprocessing workflow for imaging and de-risking CO2 storage Reservoirs and Seals. The workflow includes statics, demultiple, velocity modeling, Prestack Time Migration, high resolution sparse spike deconvolution and Non Local Means filtering. Non Local Means filtering increases signal to noise ratio while preserving edges and the sparse spike deconvolution produces results with superior vertical and lateral resolution. This workflow manages at low cost to considerably de-risk the CO2 storage Reservoirs and Seals by identifying previously hidden faults, Seal-Reservoir contacts and thin Reservoir streaks.