Comprehensive Application of Fluid Properties and Seismic Interpretation in Research on Oil and Gas Migration: An Example of Bashituopu Reservoir in Markit Slope in Tarim Basin

In order to reveal in middle fault depression belt of Hailer-Tamtsag Basin buried hill oil and gas migration and accumulation characteristics, we summarize controlling effect of fault on oil and gas migration and accumulation of buried hill, which by analysing genetic mechanism of buried hills based on fault systems formation and evolution. Research shows that three types of fault system in Hailer-Tamtsag Basin: early stretched fault system(Type I), early stretched middle tensile shearing fault system(Type I-II), early stretched middle tensile shearing reverse late fault system(Type I-II-III). Type I-II and I-II-III are stretching by NW tensional stress in Nantun group ,which afford tectonic framework for syngenesis buried hill and epigenetic buried hill. Type I make buried hills complicated .It is also favorable to ancient geomorphological buried hill in the fault less affected zones. Although they formed cracks dense zone easier, Type I-II and I-II-III fault system damage the reservoir which is not conducive to " hydrocarbon-supplying window " formation; Type I fault system have less promotion on the development of the buried hill reservoir, while it is conducive to hydrocarbon accumulation as the block boundary in buried hill hydrocarbon. Fault formed source rocks two kinds for hydrocarbon mode: unidirectional and bidirectional, which formed two reservoir-forming pattern: Unidirectional transportation hydrocarbon of weathering crust or hydrocarbon of fracture damage zones and bidirectional transportation hydrocarbon of weathering crust or hydrocarbon of fracture damage zones.

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Controlling Factors of Hydrocarbon Accumulation in Talaha-Changjiaweizi Area

Advanced Materials Research ◽

10.4028/www.scientific.net/amr.734-737.1175 ◽

2013 ◽

Vol 734-737 ◽

pp. 1175-1178

Author(s):

Hong Qi Yuan ◽

Ying Hua Yu ◽

Fang Liu

Keyword(s):

Physical Properties ◽

Oil And Gas ◽

Controlling Factors ◽

Source Rocks ◽

Hydrocarbon Accumulation ◽

Gas Migration ◽

Main Controlling Factors ◽

Sedimentary Microfacies ◽

Plane Distribution ◽

Distributary Channel

Based on the analysis of the relationships between the conditions of structures, sedimentations, source rocks, cap rocks, faults, oil and gas migration passages and traps and hydrocarbon accumulation, the controlling factors of hydrocarbon accumulation and distribution was studied in Talaha-changjiaweizi area. It is held that the source rocks control the hydrocarbon vertical distribution, the drainage capabilities control the hydrocarbon plane distribution, fracture belts control the hydrocarbon accumulation of Talaha syncline, underwater distributary channel is a favorable accumulation environment and reservoir physical properties control the oil and water distributions. Therefore, it is concluded that source rocks, fracture belts, sedimentary microfacies and reservoir physical properties are the main controlling factors of hydrocarbon accumulation and distribution in Talaha-changjiaweizi area.

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Seismic attribute for characterization and prediction of carbonate faulted karst reservoirs in Tarim Basin, China

Interpretation ◽

10.1190/int-2019-0162.1 ◽

2021 ◽

pp. 1-36

Author(s):

Zhiwei Xiao ◽

Li Wang ◽

Ruizhao Yang ◽

Dewei Li ◽

Lingbin Meng

Keyword(s):

Tarim Basin ◽

Oil And Gas ◽

Prediction Method ◽

Strike Slip ◽

Fault System ◽

Bright Spot ◽

Upper Ordovician ◽

Reservoir Prediction ◽

Seismic Attribute ◽

Gas Field

An ultradeep, faulted karst reservoir of Ordovician carbonate was discovered in the Shunbei area of the Tarim Basin. Fractured-cavity reservoirs buried beneath the large thickness of upper Ordovician mudstone were formed along the fault-karst belts. The hydrocarbon accumulation in these reservoirs is controlled by the fault system, and the oil-gas accumulation was affected by karstification and hydrothermal reformation. Previous studies and 2D modeling revealed that the reservoirs had “bright spot” amplitude responses like “string beads,” and they have developed along the strike-slip faults. However, describing such a complex fault-controlled karst system is still a difficult problem that has not been well addressed. We have sought to instruct the attribute expression of faulted karst reservoirs in the northern part of the Tarim Basin. We applied coherence and fault likelihood (FL) seismic attributes to image faults and fractures zones. We then used a trend analysis method to calculate the residual impedance from the impedance of the acoustic inversion, using the fact that residual impedance has higher lateral resolution in reservoir predictions. Finally, we integrated the coherence, FL, and residual impedance attributes into a new seismic attribute, the “fault-vuggy body,” with a certain fusion coefficient. The fault-vuggy body attribute establishes a connection between faults and karst cavities. This method could help in the characterization and prediction of carbonate faulted karst reservoirs. Available drilling data were used to validate that the fused fault-vuggy body attribute was an effective reservoir prediction method. As the seismic sections and slices along the layer help delineate, the distribution of bright spots and strike-slip faults indicates that the main strike-slip fault zones are the most favorable reservoirs in the Shunbei Oil and Gas Field.

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3-D Numerical Simulations of Subsea Jumper Transporting Intermittent Slug Flows

Volume 2: CFD and FSI ◽

10.1115/omae2018-77299 ◽

2018 ◽

Author(s):

Jihyeon Kim ◽

Narakorn Srinil

Keyword(s):

Slug Flow ◽

Oil And Gas ◽

Process Condition ◽

Structural Response ◽

Dynamic Responses ◽

Operating Pressure ◽

Computational Performance ◽

Fluid Properties ◽

Slug Flows ◽

Interaction Approach

Subsea jumper is the steel pipe structure to connect wellhead and subsea facilities such as manifolds or processing units in order to transport the produced multiphase flows. Generally, the jumper consists of a goalpost with two loop structures and a straight pipe between them, carrying the multiphase oil and gas from the producing well. Due to the jumper pipe characteristic geometry and multi-fluid properties, slug flows may take place, creating problematic fluctuating forces causing the jumper oscillations. Severe dynamic fluctuations cause the risk of pipe deformations and resonances resulting from the hydrodynamic momentum/pressure forces which can lead to unstable operating pressure and decreased production rate. Despite the necessity to design subsea jumper with precise prediction on the process condition and the awareness of slug flow risks, it is challenging to experimentally evaluate, identify and improve the modified design in terms of the facility scale, time and cost efficiency. With increasing high computational performance, numerical analysis provides an alternative approach to simulate multiphase flow-induced force effects on the jumper. The present paper discusses the modelling of 3-D flow simulations in a subsea jumper for understanding the development process of internal slug flows causing hydrodynamic forces acting on the pipe walls and bends. Based on the fluctuating pressure calculated by the fluid solver, dynamic responses of the jumper pipe are assessed by a one-way interaction approach to evaluate deformation and stress. A potential resonance is discussed with the jumper modal analysis. Results from the structural response analyses show dominant multi-modal frequencies due to intermittent slug flow frequencies. Numerical results and observed behaviors may be useful for a comparison with other simulation and experiment.

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Predicting gas migration through existing oil and gas wells

Environmental Geosciences ◽

10.1306/eg.01241817008 ◽

2018 ◽

Vol 25 (4) ◽

pp. 121-132 ◽

Cited By ~ 6

Author(s):

James A. Montague ◽

George F. Pinder ◽

Theresa L. Watson

Keyword(s):

Oil And Gas ◽

Gas Migration ◽

Gas Wells ◽

Oil And Gas Wells

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Fluid geochemistry of the Jurassic Ahe Formation and implications for reservoir formation in the Dibei area, Tarim Basin, northwest China

Energy Exploration & Exploitation ◽

10.1177/0144598718759560 ◽

2018 ◽

Vol 36 (4) ◽

pp. 801-819 ◽

Cited By ~ 1

Author(s):

Shuangfeng Zhao ◽

Wen Chen ◽

Zhenhong Wang ◽

Ting Li ◽

Hongxing Wei ◽

...

Keyword(s):

Natural Gas ◽

Tarim Basin ◽

Oil And Gas ◽

Northwest China ◽

Source Rocks ◽

Coal Measure ◽

Hydrocarbon Generation ◽

Gas Reservoirs ◽

Isotopic Analyses ◽

Jurassic Coal

The condensate gas reservoirs of the Jurassic Ahe Formation in the Dibei area of the Tarim Basin, northwest China are typical tight sandstone gas reservoirs and contain abundant resources. However, the hydrocarbon sources and reservoir accumulation mechanism remain debated. Here the distribution and geochemistry of fluids in the Ahe gas reservoirs are used to investigate the formation of the hydrocarbon reservoirs, including the history of hydrocarbon generation, trap development, and reservoir evolution. Carbon isotopic analyses show that the oil and natural gas of the Ahe Formation originated from different sources. The natural gas was derived from Jurassic coal measure source rocks, whereas the oil has mixed sources of Lower Triassic lacustrine source rocks and minor amounts of coal-derived oil from Jurassic coal measure source rocks. The geochemistry of light hydrocarbon components and n-alkanes shows that the early accumulated oil was later altered by infilling gas due to gas washing. Consequently, n-alkanes in the oil are scarce, whereas naphthenic and aromatic hydrocarbons with the same carbon numbers are relatively abundant. The fluids in the Ahe Formation gas reservoirs have an unusual distribution, where oil is distributed above gas and water is locally produced from the middle of some gas reservoirs. The geochemical characteristics of the fluids show that this anomalous distribution was closely related to the dynamic accumulation of oil and gas. The period of reservoir densiﬁcation occurred between the two stages of oil and gas accumulation, which led to the early accumulated oil and part of the residual formation water being trapped in the tight reservoir. After later gas filling into the reservoir, the fluids could not undergo gravity differentiation, which accounts for the anomalous distribution of fluids in the Ahe Formation.

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Gas migration from oil and gas fields and associated hazards

Journal of Petroleum Science and Engineering ◽

10.1016/0920-4105(93)90016-8 ◽

1993 ◽

Vol 9 (3) ◽

pp. 223-238 ◽

Cited By ~ 36

Author(s):

A.E. Gurevich ◽

B.L. Endres ◽

J.O. Robertson ◽

G.V. Chilingar

Keyword(s):

Oil And Gas ◽

Gas Migration ◽

Oil And Gas Fields ◽

Gas Fields

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Hydrocarbon Distribution Pattern in the Upper Ordovician Carbonate Reservoirs and its Main Controlling Factors in the West Part of Northern Slope of Central Tarim Basin, NW China

Energy Exploration & Exploitation ◽

10.1260/0144-5987.30.5.775 ◽

2012 ◽

Vol 30 (5) ◽

pp. 775-792 ◽

Cited By ~ 6

Author(s):

Xiuxiang Lü ◽

Jianfa Han ◽

Xiang Wang ◽

Weiwei Jiao ◽

Hongfeng Yu ◽

...

Keyword(s):

Physical Properties ◽

Distribution Pattern ◽

Tarim Basin ◽

Oil And Gas ◽

Petroleum Exploration ◽

Chemical Compositions ◽

Northern Slope ◽

Upper Ordovician ◽

The West ◽

West Part

The northern slope of Tazhong palaeo-uplift has become a key target field for petroleum exploration in Tarim Basin. A major breakthrough is made in the Upper Ordovician oil and gas exploration in the west part of northern slope. Oil and gas near the Tazhong I slope-break zone occurred in Liang2 section was dominated by condensate gas reservoir, while oil reservoir was mainly inward distributed in Liang3 section. The crude oils in this region in physical properties characterized by low density, low viscosity, low freezing point, low sulfur content, medium wax content. And the natural gas in chemical components was featured by low-medium nitrogen content, low-medium carbon dioxide content and medium-high hydrogen sulfide content. In the plane direction, oil and gas exhibited a “oil in the interior, gas in the exterior” distribution pattern, and mainly located in a depth range of 0∼60 m below the top of the Liang3 section in the longitudinal direction. The distribution patterns displayed in physical properties and chemical compositions of oil and gas are controlled by multiple influencing factors. The results of above comprehensive studies suggested that vertical overriding of reef-bank-type reservoirs in Liang2 section and karst reservoirs in Liang3 section provided superior reservoir conditions; faults and fractures not only formed reservoir space and improved reservoir quality, also promoted the development of karst reservoirs and provided good migration pathway for hydrocarbon accumulation; one of the nonnegligible factors leading to this kind of distribution pattern for the Upper Ordovician oil and gas reservoirs is shale content in the compact carbonate formation; multi-sources and multi-stages of hydrocarbon filling are absolutely necessary controlling factor for this kind of distribution pattern in the whole block.

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