Unraveling the reservoir heterogeneity of the tight gas sandstones using the porosity conditioned facies modeling in the Whicher Range field, Perth Basin, Western Australia

Kadkhodaie-Ilkhchi, Rahim; Kadkhodaie, Ali; Rezaee, Reza; Mehdipour, Vali

doi:10.1016/j.petrol.2019.01.020

Cited by 27 publications

(7 citation statements)

References 26 publications

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“…In tight sandstone gas reservoirs, the ion composition of formation water has undergone a complex and long evolution process like that of hydrocarbons. 46 In the hydrogeological development stage such as deposition, burial, and metamorphism, the water type and chemical characteristics will change, which also affect the migration, accumulation, and preservation of hydrocarbons. The Cl – content in the formation water samples is the highest followed by Na + , Ca 2+ , SO 4 2– , HCO 3 – , and Mg 2+ ( Figure 5 ).…”

Section: Resultsmentioning

confidence: 99%

Indication of Formation Water Geochemistry for Hydrocarbon Preservation: New Applications of Machine Learning in Tight Sandstone Gas Reservoirs

Yang

Wang

et al. 2022

ACS Omega

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The migration of formation water plays a crucial role in hydrocarbon accumulation and preservation. The hydrodynamic field controls the content of various ions in formation water and is an important participant in hydrocarbon evolution. One potential high-yield gas field is the tight sandstone gas reservoirs in the northern Tianhuan Depression of the Ordos Basin, China. However, due to the complex gas–water relationship and limited water sample data, the development of gas reservoirs has encountered great difficulties; we thus analyzed the geochemical characteristics of a large scale of formation water acquired from the Permian in the Ordos Basin (60 water samples collected from 45 wells in the He8 Member). The results showed that formation water is the original sedimentary water in tight sandstone reservoirs, which represent a closed hydrological environment, which is conducive to gas accumulation. This is also related to the demonstrated strong water–rock reaction and diagenetic. We also developed a statistical model between these geochemical parameters and gas preservation based on machine learning algorithms (decision trees). Note that machine learning, as a data-driven artificial intelligence algorithm, generates massive correlation models that can learn from the structured training data sets to carry out predictions or evaluations in newly presented data. This algorithm can process large amounts of information data more quickly and can build more perfect correlation models through deep learning mechanisms than traditional statistical methods. The results suggest that the metamorphism coefficient has the best indication effect on the preservation of gas reservoirs. The hydrological environment with (Cl–-Na+)/Mg2+ > 50.066, Na+/Cl– ≤ 0.476, and Ma2+/Ca2+ ≤ 0.102 is a good hydrocarbon accumulation area. This study can be applied, by analogy, to more comprehensively interpret the correlation between the geochemical characteristics of formation water and hydrocarbon storage and to improve the accuracy of predicting favorable hydrocarbon accumulation areas in tight sandstone gas reservoirs.

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Section: Resultsmentioning

confidence: 99%

Indication of Formation Water Geochemistry for Hydrocarbon Preservation: New Applications of Machine Learning in Tight Sandstone Gas Reservoirs

Yang

Wang

et al. 2022

ACS Omega

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“…From the perspective of chemical reaction, the carbonate gas reservoir is essentially a mixed system of brine, dolomite, and natural gas and many chemical reactions have taken place in the geological period [43].…”

Section: Ion Concentrationmentioning

confidence: 99%

Geochemical Characteristics of Formation Water in Carbonate Reservoirs and Its Indication to Hydrocarbon Accumulation

Sun

Yang

et al. 2022

Geofluids

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The migration path of formation water plays an indispensable role in hydrocarbon accumulation and preservation. The hydrodynamic field controls the content of various ions in formation water and is an important participant in hydrocarbon evolution. Formation water can basically be used to judge the preservation status of oil/gas reservoirs, especially for carbonate reservoirs; the carbonate reservoirs are a typical example in the Gaoqiao area of the Ordos Basin, China. However, it is not easy to evaluate the sealing and integrity of the gas reservoir because hydrocarbon has experienced a multistage charging process and complicated later reconstruction. The geochemical characteristics of Ordovician formation water (100 brine samples from 67 wells in the Ma5 Member) are studied, and their chemical composition is analyzed in the Ordos Basin. The results show that formation water has high overall salinity and is the original sedimentary water of the carbonate reservoir, which is the sealing reservoir and can promote the accumulation of hydrocarbons. This is also associated with stronger water-rock reactions and diagenetic transformations, such as dolomitization. The main (TDS) range is from 40 to 150 g·L−1, with an average of 66.16 g·L−1; the Cl− content in the formation water samples is the highest, followed by Ca2+, Na+, Mg2+, HCO3−, and SO42−. In addition, the (Cl−-Na+)/Mg2+ ratio, Na+/Cl− ratio, Mg2+/Ca2+ ratio, and S O 4 2 − × 100 / C l − ratio are closely related to gas preservation. The indication function between chemical parameters of formation water and hydrocarbon dynamics can be better understood in carbonate reservoirs by analogy study, so as to improve the accuracy of discriminating favorable hydrocarbon accumulation areas.

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“…Heterogeneity is an important property of tight reservoirs; however, how to describe the reservoir heterogeneity has always puzzled petroleum geologists [1,2]. Different from the tight gas deposited in North America, tight continental gas is widely distributed in China.…”

Section: Introductionmentioning

confidence: 99%

“…As a Chinese petroleum geologist, Qiu [3] proposed a classification criterion for reservoir heterogeneity which gained him an excellent reputation. In this classification frame, reservoir heterogeneity is divided into three categories: (1) plane heterogeneity, which refers to the heterogeneity caused by the geometry, size, and continuity of a reservoir sand body, as well as the spatial variation of porosity and permeability within the sand body [4]; (2) intralayer heterogeneity, which is mainly used to characterize the changes of vertical reservoir properties in a single sand body and is a crucial geological factor controlling and affecting the sweep thickness of the vertical injection agent in a single sand body [5]; and (3) interlayer heterogeneity, which refers to the overall study of the vertical lithology and physical property differences among sand layers in a unit, belonging to the reservoir description of the scale of strata [6]. These three types of heterogeneity are widely used to describe reservoir heterogeneity.…”

Section: Introductionmentioning

confidence: 99%

Characterization Method of Tight Sandstone Reservoir Heterogeneity and Tight Gas Accumulation Mechanism, Jurassic Formation, Sichuan Basin, China

et al. 2022

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Although significant progress has been made in tight gas exploration and development, there is still a limited understanding of the gas accumulation mechanism in tight formation. The description of heterogeneity in the tight reservoir is still an obstacle during tight gas exploration. In this work, we will develop a 3D gas accumulation facility that can reflect the high temperature and pressure under the geological condition to simulate the gas accumulation process in the tight formation of the Jurassic Formation, Sichuan Basin. Both the physical experiment simulation and numerical simulation methods will be combined to reveal the mechanism of gas accumulation. The results show that (1) the permeability ratio can characterize the heterogeneity of tight reservoirs. Based on this parameter, petroleum geologists can understand the interlayer heterogeneity during fluvial deposition and predict the sweet spots of tight gas; (2) the permeability ratio relationship between hydrocarbon accumulation of the tight sandstone reservoir mainly manifests as long as there is the existence of the differential permeability and there will be differences in natural gas migration dynamics, so that the natural gas accumulates in pores and depends on the extent of source rock; and (3) although the difference between capillary force curves is at the core of the influence of the permeability ratio on the gas-bearing capacity of the “sweet spot” sand body, the permeability ratio is a parameter of practical engineering significance. This work adds new methods to tight gas formation heterogeneity characterization and sheds light on the mechanisms of hydrocarbon accumulation in tight formation.

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Unraveling the reservoir heterogeneity of the tight gas sandstones using the porosity conditioned facies modeling in the Whicher Range field, Perth Basin, Western Australia

Cited by 27 publications

References 26 publications

Indication of Formation Water Geochemistry for Hydrocarbon Preservation: New Applications of Machine Learning in Tight Sandstone Gas Reservoirs

Indication of Formation Water Geochemistry for Hydrocarbon Preservation: New Applications of Machine Learning in Tight Sandstone Gas Reservoirs

Geochemical Characteristics of Formation Water in Carbonate Reservoirs and Its Indication to Hydrocarbon Accumulation

Characterization Method of Tight Sandstone Reservoir Heterogeneity and Tight Gas Accumulation Mechanism, Jurassic Formation, Sichuan Basin, China

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