The tight oil potential of the Lucaogou Formation from the southern Junggar Basin, China

Luo, Qingyong; Gong, Lei; Qu, Yansheng; Zhang, Kuihua; Zhang, Guanlong; Wang, Shengzhu

doi:10.1016/j.fuel.2018.07.002

Cited by 78 publications

(34 citation statements)

References 69 publications

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“…In this study, the carbon isotopic and gas chromatography–mass spectrometry (GC–MS) (Table 2) data can be used to study the depositional environment. For instance, the Pr/Ph, Pr/nC 17 and Ph/nC 18 ratios can effectively reveal the redox conditions of the source rock deposition environments (Didyk, Simoneit, Brassell, & Eglinton, 1978; Luo et al, 2018; Peters et al, 2005). The palaeoproductivity can be determined by the autochthonous organic matter production index (AOMPI) calculated from carbon isotopes, and its high value represents the high level of palaeoproductivity (Ding et al, 2016).…”

Section: Materials and Analytical Methodsmentioning

confidence: 99%

The hydrocarbon generation and expulsion features of source rocks and tight oil potential of the second member of the Qiketai Formation, Shengbei area in the Turpan–Hami Basin, NW China

et al. 2020

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Significant progress in tight oil exploration has been reported in the second member of the Qiketai Formation (J2q2) in the Shengbei area of the Turpan–Hami Basin. Geochemical analyses were conducted to assess the quality of the J2q2 source rocks. The improved hydrocarbon generation potential method was utilized to quantify the hydrocarbon generation and expulsion features of the source rocks. The results showed that J2q2 source rocks were deposited in a reduced lacustrine setting with a high palaeoproductivity. The J2q2 source rocks are widely distributed (approximately 1,000 km2) and have a thickness that varies from 50 to 130 m. Moreover, they can be identified as a set of high‐quality source rocks (thermally mature rocks with Ro values >0.5%, consisting mainly of types I and II kerogen and possessing an average total organic carbon content of 2.68%). The oil–source correlation results reveal that the source of crude oil in the studied area is J2q2. The improved hydrocarbon generation potential method is established for different kerogen types to limit the influence of the kerogen type on the calculation. The hydrocarbon expulsion threshold of the type I model is located at Ro = 0.6%. The type II kerogen rocks have different characteristics, and the hydrocarbon expulsion threshold is located at Ro = 0.62%. The maximum hydrocarbon generation and expulsion intensities are 700 × 104 t/km2 and 400 × 104 t/km2, respectively. The hydrocarbon generation and expulsion amount of the J2q2 source rocks are 21.4 × 108 t and 12.3 × 108 t, respectively. The tight oil potential of the J2q2 tight oil in the Shengbei area is 4.09 × 108 t. The SB10 and SB6 well areas are favourable J2q2 tight oil exploration areas in the Shengbei area. The SB10 well area has the highest hydrocarbon generation and expulsion intensities in the study area and is the best tight oil exploration target.

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Section: Materials and Analytical Methodsmentioning

confidence: 99%

The hydrocarbon generation and expulsion features of source rocks and tight oil potential of the second member of the Qiketai Formation, Shengbei area in the Turpan–Hami Basin, NW China

et al. 2020

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“…Previous researches on the Lucaogou Formation have focused on reservoir geology (Kuang et al 2012;Gao et al 2016;Wu et al 2016;Zhao et al 2017;Cao et al 2016Cao et al , 2017Luo et al 2018;Su et al 2018). Thus, the bed type and architecture study here represents an unreported aspect.…”

Section: Bed Types and Flow Mechanisms Of Fan Fringe Facies In The Lumentioning

confidence: 97%

“…The Middle Permian Lucaogou Formation in the Junggar Basin of NW China was selected in this study, because it represents a sub-lacustrine fan fringe facies, and the deposits of which reveal the bed types, sedimentary sequences, and sedimentary processes of a fan fringe setting. Previous studies on the Lucaogou Formation have mainly focused on reservoir characteristics (Wu et al 2016;Zhao et al 2017;Su et al 2018) and the tight oil potential (Kuang et al 2012;Gao et al 2016;Cao et al 2016Cao et al , 2017Luo et al 2018). However, few studies focus on bed-scale investigations and the sedimentary processes that allow the formation of these beds.…”

Section: Introductionmentioning

confidence: 99%

Bed type and flow mechanism of deep water sub-lacustrine fan fringe facies: an example from the Middle Permian Lucaogou Formation in Southern Junggar Basin of NW China

Shan

Jin

et al. 2020

Pet. Sci.

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Submarine or sub-lacustrine lobe deposits are important reservoirs, but the fan fringe deposits form heterogeneities within deep water fan deposits. Fan fringe facies records the complex sediment gravity flow types. By understanding of the bed types and flow mechanisms, we can identify the fan fringe deposit, which aids in the reconstruction of deep water fan and reservoir evaluations. The Jiucaiyuanzi and Dalongkou sections in the West Bogda Mountains preserve well-exposed 536-m and 171-m thick successions, respectively, of a deep water lacustrine depositional system from the Middle Permian Lucaogou Formation. Bed types of the Lucaogou Formation include high-density turbidite, low-density turbidite, incomplete Bouma-type turbidite, hybrid event beds, and slump deposits. The Lucaogou Formation is interpreted here as a fan fringe facies due to the thin bed thickness that characterize turbidites and hybrid event beds, as well as the predominance of the isolated sheet architecture. Previous studies suggest that these deposits were considered as deposited in a deep water setting due to the absence of wave-related structures. The presence of abundant mud clasts in massive medium-coarse grained sandstone beds reflects the significant erosional capability and interactions between high-density turbidity currents and lake floor. The fan fringe facies here contains amalgamated and thick-bedded homolithic facies (~ 30%) and thin-bedded heterolithic facies (~ 70%). The examination of the bed type is of wider significance for facies prediction and reservoir heterogeneity in the sub-lacustrine fan fringe facies.

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“…The cumulative volume fraction of pore throats (radius < r) could be calculated by combining Eqs. 3and (4).…”

Section: Fractal Features Of Pore Systemmentioning

confidence: 99%

“…3 Because of the successful exploration and exploitation of tight oil in North America, most of the researchers focused on marine tight oil reservoirs, while the study of lacustrine tight oil plays is still in a relatively poor stage. The research on tight oil in China just begun in the last decade, many tight oil formations were previously considered to be source rock, such as the Lucaogou formation in Junggar Basin, 4,5 Longmaxi formation in the Sichuan Basin, [6][7][8] and Yanchang formation in Ordos Basin. 9,10 Affected by the commercial development of tight oil in North America, Lucaogou tight oil reservoir were discovered recently and already act as one of the most important tight oil reservoirs in China.…”

Section: Introductionmentioning

confidence: 99%

Overall PSD and Fractal Characteristics of Tight Oil Reservoirs: A Case Study of Lucaogou Formation in Junggar Basin, China

et al. 2019

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Lucaogou tight oil reservoir, located in the Junggar Basin, Northwest of China, is one of the typical tight oil reservoirs. Complex lithology leads to a wide pore size distribution (PSD), ranging from several nanometers to hundreds of micrometers. To better understand PSD and fractal features of Lucaogou tight oil reservoir, the experiment methods including scanning electron microscope (SEM), rate-controlled mercury injection (RMI) and pressure-controlled mercury injection (PMI) were performed on the six samples with different lithology. The results indicate that four types of pores exist in Lucaogou tight oil reservoir, including dissolution pores, clay dominated pores, microfractures and inter-granular pores. A combination of PMI and RMI was proposed to calculate the overall PSD of tight oil reservoirs, the overall pore radius of Lucaogou tight oil reservoir ranges from 3.6[Formula: see text]nm to 500[Formula: see text][Formula: see text]m. The fractal analysis was carried out based on the PMI data. Fractal dimension (Fd) values varied between 2.843 and 2.913 with a mean value of 2.88. Fd increases with a decrease of quartz content and an increase of clay mineral content. Samples from tight oil reservoirs with smaller average pore radius have stronger complexity of pore structure. Fractal dimension shows negative correlations with porosity and permeability. In addition, fractal characteristics of different tight reservoirs were compared and analyzed.

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The tight oil potential of the Lucaogou Formation from the southern Junggar Basin, China

Cited by 78 publications

References 69 publications

The hydrocarbon generation and expulsion features of source rocks and tight oil potential of the second member of the Qiketai Formation, Shengbei area in the Turpan–Hami Basin, NW China

The hydrocarbon generation and expulsion features of source rocks and tight oil potential of the second member of the Qiketai Formation, Shengbei area in the Turpan–Hami Basin, NW China

Bed type and flow mechanism of deep water sub-lacustrine fan fringe facies: an example from the Middle Permian Lucaogou Formation in Southern Junggar Basin of NW China

Overall PSD and Fractal Characteristics of Tight Oil Reservoirs: A Case Study of Lucaogou Formation in Junggar Basin, China

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