Physical properties of petroleum formed during maturation of Lower Cambrian shale in the upper Yangtze Platform, South China, as inferred from PhaseKinetics modelling

Tan, Jingqiang; Horsfield, Brian; Mahlstedt, Nicolaj; Zhang, Jinchuan; Primio, Rolando di; Vu, Thi Anh Tiem; Boreham, Christopher J.; Graas, Ger van; Tocher, Bruce A.

doi:10.1016/j.marpetgeo.2013.07.013

Cited by 61 publications

(35 citation statements)

References 28 publications

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“…The PhaseKinetics model characterizes the compositional evolution of the fluids generated with increasing thermal stress, as well as the phase behaviour of the petroleum at different maturity levels (Di Primio & Horsfield 2006). Predictions of bulk petroleum compositions and physical properties have already been published for basins in South Africa (Hartwig et al 2012), North Dakota (Kuhn et al 2012), Norway (Rodrigues Duran et al 2013, eastern Canada (Baur et al 2010), Brazil (Di Primio & Horsfield 2006 and China (Tan et al 2013), in several cases with confirmation of the prediction using local calibration. In the current study we employed the PhaseKinetics approach on both whole-rock samples and kerogen concentrates to predict the properties of fluids generated from Bowland Shale, also taking into consideration the impact of rock-fluid interactions (mineral matrix effects, considered to be laboratory artefects) on the results (see Espitalie et al 1980;Horsfield & Douglas 1980).…”

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confidence: 99%

On the primary and secondary petroleum generating characteristics of the Bowland Shale, northern England

Yang

Horsfield

Mahlstedt

et al. 2015

JGS

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The Carboniferous Bowland Shale of northern England has drawn considerable attention because it has been estimated to have 1329 trillion cubic feet hydrocarbons in-place (gas and liquids) resource potential (Andrews 2013). Here we report on the oil and gas generation characteristics of three selected Bowland Shale whole-rock samples taken from cores and their respective kerogen concentrates. Compositional kinetics and phase properties of the primary and secondary fluids were calculated through the PhaseKinetics and GOR-Fit approaches and PVT modelling software. The three Bowland Shale samples contain immature, marine type II kerogen. Pyrolysate compositions imply primary generation of paraffinic–naphthenic–aromatic (PNA) oil with low contents of wax and sulphur. Bulk kinetic parameters have many similarities to those of productive American Palaeozoic marine shale plays. The secondary gas generation potential of Bowland Shale is greater than the primary gas potential although it requires a 10 kcal mol −1 higher activation energy to achieve peak production. Primary oil, primary gas and secondary gas reach their maximum generation at 137, 150 and 200°C respectively for a 3°C Ma −1 heating rate. Different driving forces of expulsion including the generation of hydrocarbon and overpressure caused by phase separation during sequential periods of subsidence and uplift could be inferred.

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confidence: 99%

On the primary and secondary petroleum generating characteristics of the Bowland Shale, northern England

Yang

Horsfield

Mahlstedt

et al. 2015

JGS

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“…Then, parallel samples were conducted for the gas adsorption capacity test with a constant temperature of 30 °C. Experimental results were fitted with the Langmuir equation to obtain the isothermal adsorption curve, and the saturated adsorption capacity was calculated (Tan et al, 2013;Wang et al, 2013).…”

Section: Samples and Methodsmentioning

confidence: 99%

“…The Lower Cambrian Niutitang Fm is similar to the Barnett shale and is a key shale-gas drilling target in Southern China. It is expected to be a site that leads to a breakthrough in shale gas exploration in China (Hao et al, 2013;Tan et al, 2013;Hu et al, 2015). However, the exploration campaign has stalled; tests revealed that only a small number of wells were found to have industrial/ commercial flows in Hubei Province owing to the overall low gas content, low percentage of desorbed gas, and uncertainty in sweet spot identification.…”

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confidence: 99%

Characteristics of Shale Reservoir and Sweet Spot Identification of the Lower Cambrian Niutitang Formation in Northwestern Hunan Province, China

Qin

Cao

Jianhua

et al. 2019

Acta Geologica Sinica (Eng)

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The accumulation and productivity of shale gas are mainly controlled by the characteristics of shale reservoirs; study of these characteristics forms the basis for the shale gas exploitation of the Lower Cambrian Niutitang Formation (Fm), Southern China. In this study, core observation and lithology study were conducted along with X‐ray diffraction (XRD) and electronic scanning microscopy (SEM) examinations and liquid nitrogen (N2) adsorption/desorption and CH4 isothermal adsorption experiments for several exploration wells in northwestern Hunan Province, China. The results show that one or two intervals with high‐quality source rocks (TOC>2 wt%) were deposited in the deep‐shelf facies. The source rocks, which were mainly composed of carbonaceous shales and siliceous shales, had high quartz contents (>40 wt%) and low clay mineral (<30 wt%, mainly illites) and carbonate mineral (<20 wt%) contents. The SEM observations and liquid nitrogen (N2) adsorption/desorption experiments showed that the shale is tight, and nanoscale pores and microscale fractures are well developed. BJH volume (VBJH) of shale ranged from 2.144×10–3 to 20.07×10–3 cm3/g, with an average of 11.752×10–3 cm3/g. Pores mainly consisted of opened and interconnected mesopores (2–50 nm in diameter) or macropores (>50 nm in diameter). The shale reservoir has strong adsorption capacity for CH4. The Langmuir volume (VL) varied from 1.63 to 7.39 cm3/g, with an average of 3.95 cm3/g. The characteristics of shale reservoir are controlled by several factors: (1) A deep muddy continental shelf is the most favorable environment for the development of shale reservoirs, which is controlled by the development of basic materials. (2) The storage capacity of the shale reservoir is positively related to the TOC contents and plastic minerals and negatively related to cement minerals. (3) High maturity or overmaturity leads to the growth of organic pores and microfractures, thereby improving the reservoir storage capacity. It can be deduced that the high percentage of residual gas in Niutitang Fm results from the strong reservoir storage capacity of adsorbed gas. Two layers of sweet spots with strong storage capacity of free gas, and they are characterized by the relatively high TOC contents ranging from 4 wt% to 8 wt%.

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“…Three shale samples (namely samples F01, F02, and F03) were cored from shale blocks obtained from an outcrop of the lower Silurian Longmaxi formation located in the Changning region of the Sichuan Basin. This area is currently the most promising location of marine shale gas exploration in China . The samples were first cut into length of 100 mm and diameter of 50 mm.…”

Section: Laboratory Experimental Analysismentioning

confidence: 99%

Permeability model of fractured rock with consideration of elastic‐plastic deformation

Zhao

Wang

2019

Energy Science & Engineering

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The evolution of rock permeability has been studied exhaustively, and a broad array of permeability models has been proposed. These models are normally derived under the assumption of elastic deformation when subjected to external stress. Under this assumption, these models define fracture permeability as a function of either gas pressure or effective stress. However, experimental observations indicate that rock fracture may experience unrecoverable deformation during the loading process. The goal of this study is to resolve this contradiction. In this study, derivation of fracture permeability correlation for elastoplastic contact of rough surfaces is presented. The proposed method for describing permeability evolution not only considers the topography of fracture surfaces but also and, more importantly, integrates the plastic deformation of rock fracture. Subsequently, the deformation and permeability change of shale sample containing a single rough‐walled fracture is experimentally investigated. The results show that the permeabilities obtained during the loading process are larger than the permeabilities obtained during the unloading process under the same stress conditions and that the fracture deformation cannot be fully recovered during the unloading process. At last, the proposed permeability model is applied to the experimental results and it is shown that the proposed model can predict the laboratory permeability data.

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Physical properties of petroleum formed during maturation of Lower Cambrian shale in the upper Yangtze Platform, South China, as inferred from PhaseKinetics modelling

Cited by 61 publications

References 28 publications

On the primary and secondary petroleum generating characteristics of the Bowland Shale, northern England

On the primary and secondary petroleum generating characteristics of the Bowland Shale, northern England

Characteristics of Shale Reservoir and Sweet Spot Identification of the Lower Cambrian Niutitang Formation in Northwestern Hunan Province, China

Permeability model of fractured rock with consideration of elastic‐plastic deformation

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