Impacts of the tectonic stress field on natural gas migration and accumulation: A case study of the Kuqa Depression in the Tarim Basin, China

Zeng, Lianbo; Wang, Hongjun; Gong, Lei; Liu, Benming

doi:10.1016/j.marpetgeo.2010.04.010

Cited by 140 publications

(50 citation statements)

References 37 publications

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“…Anticlines related to faults are the main structural traps in the petroleum systems. Faults communicate with the reservoir but not communicate with the cap rock played important roles for the hydrocarbon migration and accumulation (Zou et al, 2006;Zeng et al, 2010;Zhu et al, 2013). In fact, faulting provides an pathway for gas to vertically charge the reservoirs in the Kuqa depression (Shi et al, 2004).…”

Section: Petroleum Systemsmentioning

confidence: 99%

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Depositional and Diagenetic Controls on Pore Structure of Tight Gas Sandstone Reservoirs: Evidence from Lower Cretaceous Bashijiqike Formation in Kelasu Thrust Belts, Kuqa Depression in Tarim Basin of West China

et al. 2015

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Deeply buried Lower Cretaceous Bashijiqike sandstones are important gas exploration targets in the Kelasu thrust belt, Kuqa Depression of Tarim Basin in China. The sandstones are characterized by low porosity, low permeability and strong microscopic heterogeneity due to diagenesis during their geologic history. Mineralogical, petrographic, and geochemical analyses combined with high-pressure mercury injection analysis have been used to investigate the diagenesis, diagenetic minerals, and their impact on reservoir quality. This article addresses the controls exerted by depositional parameters and diagenetic modifications on pore-network characteristics (porosity, pore types, sizes, shapes, and distribution), with the aim to unravel the formation mechanisms of this complex pore structures, and to improve the characterization and classification evaluation for the Bashijiqike sandstone reservoirs. The Bashijiqike sandstones are dominated by lithic arkoses and feldspathic litharenite. The pore system consists of intergranular macropores, intergranular micropores, and intragranular pores. Framework grains are generally heavily compacted. Authigenic quartz, authigenic feldspar, clay minerals and carbonates are the major pore-filling constituents. The pore structure is characterized by small pore radius and poor interconnectivity. Entry pressure reflects the microscopic pore network and macroscopic reservoir property characteristics. Pore structure characteristics are linked to the depositional parameters, type and degree of diagenesis. Clays do not control reservoir pore networks alone, and pores and pore throats are wider in coarser grained sandstones. Entry pressure decreases with the content of the rigid quartz. Compaction and cementation continue to decrease the pore-throat size, while dissolution enlarges pores and pore-throats radius. Considerable amounts of microporosity associated with clay minerals and altered grains contribute to the high entry pressure. Comprehensive Coefficient of Diagenesis (CCD), which considers the integrative effect of diagenesis, shows strong statistical correlations with entry pressure. CCD is an integrative modulus of diagenesis and physical property, and generally the higher the values are, the better the pore structure. It is suitable for quantitatively characterizing pore structure in tight gas sandstones. The results of this work can help assess pore-network characteristics like the Bashijiqike sandstones which had experienced strong diagenetic modifications during their geological history.

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Section: Petroleum Systemsmentioning

confidence: 99%

“…Schematic stratigraphy and hydrocarbon source rocks, reservoirs and cap rocks in the Kuqa Depression within the Tarim Basin (modified after Zhao et al, 2005 andZeng et al, 2010).…”

Section: Figmentioning

confidence: 99%

Depositional and Diagenetic Controls on Pore Structure of Tight Gas Sandstone Reservoirs: Evidence from Lower Cretaceous Bashijiqike Formation in Kelasu Thrust Belts, Kuqa Depression in Tarim Basin of West China

et al. 2015

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“…According to the analysis of the time-space matching relation of gas accumulation and the inclusions of the Kela-2 gas field, it is considered that the Neogene is the key time of gas accumulation (Song and Wang, 2003;Lu et al, 2012;Zeng et al, 2010) (Fig. 18).…”

Section: Effects Of Neotectonic Movement On the Formation Of Gas Resementioning

confidence: 99%

The characteristics of the neotectonic movement and their effects on the formation of gas reservoirs in the marginal depressions of Tarim basin, NW China

Jiang

Huang

et al. 2015

Journal of Natural Gas Science and Engineering

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“…Also, several physical modelling experiments have been conducted on piston-forwarding gas-water inversion accumulation (Gies, 1984;Pang, Jin, & Jiang, 2003;Xiao, Zhong, Huang, Jiang, & Liu, 2008). For example, tight-sand reservoirs in the western Sichuan Depression of the Sichuan Basin and Kuqa Depression of the Tarim Basin generally experienced complicated tectonic movements, especially the Himalayan tectonic movement, which resulted in wide fracture growth in tight sand reservoirs (Zeng & Liu, 2006;Zeng, Wang, Gong, & Liu, 2010). However, different from these typical continuous tight-sand gas reservoir in North America, natural fractures are well-developed in tight sands and play important role in successful and economic production of gas from tight-sand reservoirs in the foreland basin in the Tarim Basin, Northwest China.…”

Section: Introductionmentioning

confidence: 99%

Characteristics of dual media in tight‐sand gas reservoirs and its impact on reservoir quality: A case study of the Jurassic reservoir from the Kuqa Depression, Tarim Basin, Northwest China

et al. 2017

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The recent gas exploration in West China demonstrated that formation conditions of tight‐sandstone gas are distinct from typical ones in North America. One remarkable difference is that complicated tectonic conditions in the foreland basin of West China, especially the Himalayan tectonic movement, resulted in widely developed fractures in tight‐sand reservoirs. Thus, this work employed dual media to characterize tight‐sand reservoir system and explain the impact of dual media on tight‐sand gas reservoir by: (a) describing the feature of fractures and properties of Yinan 2 tight‐sand reservoir; (b) characterizing dual media with mercury intrusion porosimetry, full diameter and conventional core analysis; (c) discussing gas charging and accumulating in dual media based on the difference between dual media and tight‐sand rocks. Observation from cores, FMI images and thin sections suggested that macro‐ and micro‐fractures are widely distributed in Lower Jurassic Ahe Formation (J1a) tight sandstones, with dip angle of 70° to 80°. These fractures are strongly scale‐dependent with length of several centimetres to a few tens of centimetres and apertures of several hundreds to several thousands of microns. J1a tight‐sand reservoir is characterized by poor porosity, with an average value of 7.7%, whereas measured permeability varies from 0.01–100 mD. Intrusion and extrusion curves of dual media and tight‐sand rocks are significantly different from each other, while displacement pressure and medium saturation pressure of dual media are lower than tight‐sand rocks. Importantly, maximum pore throats of dual media are 1.75–32.22 times larger than juxtaposed tight‐sand rocks. The ratio of permeability between dual media and tight sandstone is up to 1,000, whereas the ratio of porosities only ranges from 1 to 1.5. Thus, dual media in tight‐sand reservoir represents high permeability system and matrix pores are primarily storage system. The impact of dual media on tight‐sand gas reservoir involves its position, temporal coupling of gas charging and growth. In terms of fracture growth prior to gas charge, multi‐force can work together as a driving force, and fractures as a flow system and matrix pores as a storage system linked by fractures; buoyancy is the primary driving force in fractures. In terms of gas charge prior to fracture growth, dual media can also exert a positive impact on gas charging when occurring in the inner part of tight‐sand reservoir defined by the critical throat threshold. However, dual media can also destroy the “inverted gas–water” and shrink tight‐sand gas reservoir when occurring at the original critical throat threshold.

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Impacts of the tectonic stress field on natural gas migration and accumulation: A case study of the Kuqa Depression in the Tarim Basin, China

Cited by 140 publications

References 37 publications

Depositional and Diagenetic Controls on Pore Structure of Tight Gas Sandstone Reservoirs: Evidence from Lower Cretaceous Bashijiqike Formation in Kelasu Thrust Belts, Kuqa Depression in Tarim Basin of West China

Depositional and Diagenetic Controls on Pore Structure of Tight Gas Sandstone Reservoirs: Evidence from Lower Cretaceous Bashijiqike Formation in Kelasu Thrust Belts, Kuqa Depression in Tarim Basin of West China

The characteristics of the neotectonic movement and their effects on the formation of gas reservoirs in the marginal depressions of Tarim basin, NW China

Characteristics of dual media in tight‐sand gas reservoirs and its impact on reservoir quality: A case study of the Jurassic reservoir from the Kuqa Depression, Tarim Basin, Northwest China

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