Jinjun Xu

University of Jinan

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Qingtao Meng

Capital Medical University

Da Lou

China University of Petroleum, East China

Zhaojun Liu

Zhejiang University

Fuqi Cheng

China University of Petroleum, East China

Qiang Jin

Beijing Tian Tan Hospital

Xiangang Cheng

China University of Petroleum, East China

Pingchang Sun

Jilin University

Yu Song

China University of Mining and Technology

Yinbo Xu

Shaanxi Research Design Institute of Petroleum and Chemical Industry

Shunan Peng

China University of Petroleum, East China

Cooperative Institutions

Chinese Academy of Sciences

China University of Petroleum, East China

Jilin University

Sinopec (China)

China University of Petroleum, Beijing

China University of Geosciences

China National Petroleum Corporation (China)

Schlumberger (British Virgin Islands)

China University of Geosciences (Beijing)

University of Chinese Academy of Sciences

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High resolution geochemical analysis of organic matter accumulation in the Qingshankou Formation, Upper Cretaceous, Songliao Basin (NE China)

International Journal of Coal Geology (2015)

Jinjun Xu Achim Bechtel Reinhard F. Sachsenhofer Zhaojun Liu Reinhard Gratzer

10.1016/j.coal.2015.03.003

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Citations (48)

Tight oil play characterisation: the lower–middle Permian Lucaogou Formation in the Jimusar Sag, Junggar Basin, Northwest China

Australian Journal of Earth Sciences (2016)

Tao Hu Xiongqi Pang X. Wang Hong Pang Yang Liu

The lower–middle Permian Lucaogou (P2l) Formation is a "sandwich-type'' combination of source rocks and reservoirs that is considered to be a potential tight oil reservoir in the Jimusar Sag (JS). We investigated the P2l Formation using a designated workflow to assess its potential as a viable tight oil reservoir play using geological, petrographical, petrophysical, and geochemical characterisation of core samples. The results showed that the P2l source rocks have a widespread distribution (up to 1500 km2), a huge thickness (up to 160 m), a relatively high abundance of organic matter (averaging 3.12 wt%), a good sapropelic quality, and a moderate thermal maturity. The reservoir consists mainly of dolomites and siltstones, predominantly characterised by secondary dissolved pores, with medium–high porosity (averaging 9.1%) and relative low permeability (averaging 0.26 mD), high abundance of brittle minerals (averaging 87.1%), and low abundance of clay minerals (averaging 11.2%) with low water sensitivity. The results demonstrate that in the JS area the P2l Formation has great potential for tight oil production with its considerable hydrocarbon expulsion quantities, good oil storage capability, and reservoir frackability potential and provide a basis for further evaluation of the tight oil potential of the P2l Formation in the wider Junggar Basin and for identifying similar plays elsewhere.

Petrophysics

Tight oil

10.1080/08120099.2016.1203817

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Citations (17)

Cenozoic lithologic interpretation of seismic data and geological significance of the northern depression of Dunhua Basin

Global geology (2013)

Jinjun Xu

Six third-order sequences in Paleogene Hunchun Formation and Neogene Tumenzi Formation in the northern depression of Dunhua Basin have been identified.By extracting the wavelets through multi-channel seismic statistical method and making synthetic seismic record of DC1 well,the authors completed the horizon calibration.Using the high-resolution inversion data volumes got from model-based well constraint in sequence stratigraphic framework,the authors depicted the plane distribution characteristics of sand content and sand thickness of the target layer.The contour maps of sand content showed that the provenance was mainly from the southeast of the sag during the deposition of the SH1-ST2.Throughout the Cenozoic sedimentary period,the supply directions of provenance did not change much,but the intensity gradually strengthened.The low-value areas of sand content,the high-value areas of the mudstone thickness,the high-value areas of the stratigraphic thickness and the high-value areas of tectonic subsidence were coincident in each sequence unit,indicating that the fractures had strong control on the deposition.The high-value areas of mudstone thickness were the main developmental areas for the mudstone,where were mainly semi-deep lake-deep lake deposits,thus,it can be preliminary predicted that these areas would be the most potential areas of hydrocarbon source rocks.

Lithology

Neogene

Paleogene

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Combined Source and Maturity Influence on Molecular Tracers and Implications For Oil-Source Correlation in Deep Reservoirs

30th International Meeting on Organic Geochemistry (IMOG 2021) (2021)

Xuan Ma M. Li P. Liu Jinjun Xu Q. Chen

Summary In this study, geochemical characteristics of two Devonian oil families in Western Canada Sedimentary Basin (WCSB) will be used as an example, to demonstrate the source affected trends in thermal maturation of common biomarker compounds in crude oils. Our results suggest that deconvolution of the possible source and maturity effects is necessary to ensure the effective application of molecular tracers in oil-source correlation of the deep petroleum systems. Comparison of the molecular parameters for the three sample sets reveals several distinct compositional straits for the evaporate and carbonate sourced oils. The most important feature of the chemical composition and molecular distributions for these oils is the significant variation in the concentrations of sulfur containing compounds and the abundance of 17(H)-hopanes relative to other terpenoid components such as 8,14-secohopanes, C23 tricyclic terpane, C24 tetracyclic terpane, 18(H)-22,29,30-trisnorneohopane (Ts) and 18(H)-30-norneohopane (C29Ts). These oils form several continuums between the extreme end members of terpane and sterane distributions likley reflecting the inherited differences in source character, diagenetic change, and thermal cracking effects between the sulfate and iron-rich source rocks. Recognizing lithofacies signature and matrix effects is important for deep reservoired fluids, as it could signficantly increase the confidence of biomarker data interpretation.

Sterane

Energy source

10.3997/2214-4609.202134211

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Fatigue Life Analysis and Equal Life Optimization Design of Fluid End of Septuple Fracturing Pump

Journal of Physics Conference Series (2024)

Bo Wang Huan-hui Zhou Chong-sheng Zhao Kai Huang Ma Cheng

Abstract To determine the cause of failures phenomenon of fatigue cracks in the crossbore area of septuple fracturing pump 4 inch fluid end, optimal design the fluid end based on the idea of equal fatigue life to reduce non-uniformity and prolong fatigue life. Firstly, the static finite element analysis under 14 design conditions and 1 test condition are calculated, the results fulfill the static strength requirements. Next, based on the static of 14 actual working conditions, find cycle peaks through constant amplitude alternating load, the fatigue life and distribution rule were calculated. Then, increase the single side width increment e to 75mm, non-uniformity between 7 cylinders is reduced from 26.6% to 1.35%, the fatigue life is prolonged by 98.2%. Finally, by parameter optimization of the crossbore fillet radius Ru to 15mm and reducing the distance from the central axis of the suction cylinder to the top 25mm, the non-uniformity of the cylinder 4 is reduced from 20.07% to 7.67%, the fatigue life is prolonged by 40.9%, and it is prolonged by 179.4% totally. The results show that the analysis method by finding cycle peaks can accurately calculate the fluid end fatigue life. The equal fatigue life parameter optimization approach has obvious consult significance for reduce non-uniformity and prolong fatigue life of septuple fluid end.

Fracturing fluid

10.1088/1742-6596/2834/1/012053

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Hydrocarbon generation from Carboniferous-Permian coaly source rocks in the Huanghua depression under different geological processes

Petroleum Science (2020)

Jinjun Xu Qiang Jin

Abstract Natural gas and condensate derived from Carboniferous-Permian (C-P) coaly source rocks discovered in the Dagang Oilfield in the Bohai Bay Basin (east China) have important implications for the potential exploration of C-P coaly source rocks. This study analyzed the secondary, tertiary, and dynamic characteristics of hydrocarbon generation in order to predict the hydrocarbon potentials of different exploration areas in the Dagang Oilfield. The results indicated that C-P oil and gas were generated from coaly source rocks by secondary or tertiary hydrocarbon generation and characterized by notably different hydrocarbon products and generation dynamics. Secondary hydrocarbon generation was completed when the maturity reached vitrinite reflectance ( R o ) of 0.7%–0.9% before uplift prior to the Eocene. Tertiary hydrocarbon generation from the source rocks was limited in deep buried sags in the Oligocene, where the products consisted of light oil and gas. The activation energies for secondary and tertiary hydrocarbon generation were 260–280 kJ/mol and 300–330 kJ/mol, respectively, indicating that each instance of hydrocarbon generation required higher temperature or deeper burial than the previous instance. Locations with secondary or tertiary hydrocarbon generation from C-P coaly source rocks were interpreted as potential oil and gas exploration regions.

Light crude oil

Energy source

10.1007/s12182-020-00513-2

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Citations (4)

Study on the Optimization of the Integrated Process Parameters of Fracturing and Flooding in Beach Bar Sand Reservoir

50th U.S. Rock Mechanics/Geomechanics Symposium (2023)

Li Ma Cong Lu Jianchun Guo Y. C. Wang Zhenxue Jiang

ABSTRACT The beach bar sand reservoir has the characteristics of low porosity and permeability, multiple thin layers and strong vertical heterogeneity. In recent years, the integrated technology of fracturing and flooding has been put forward. Based on the geological model of injection-production well group, optimization of water injection parameters of fracturing-flooding and the optimization of production well fracture parameters under the condition of fracturing and flooding are carried out in the stimulation of beach bar sand reservoirs. The research results show that optimizing the water injection volume of fracturing-flooding based on numerical simulation is 50000∼100000 m3, and the water injection rate of fracturing-flooding is 0.7∼0.9 m3/min, which can reduce the risk of production well water channeling and achieve the goal of balanced water injection. Then, the front edge of water injection in fracturing-flooding is determined by analyzing the sweep area of fracturing water injection. Based on the well spacing and ultimate flow distance of low permeability reservoirs, the half length of fractures in different types of production wells was optimized. The research results can effectively guide the economic and efficient development of beach bar sand reservoirs under the condition of fracturing-flooding and water injection. INTRODUCTION Bin435 block of Shengli Oilfield is located in Binzhou City, Shandong Province. It is structurally located in the west slope of Lijin depression. Oil layers are drilled in the upper S4 sub-member of Shahejie Formation. The area of the work area is 1.23 km2 and the crude oil reserves are 208 × 104 t. The upper sub-member of the target layer of Shahejie Formation consists of 1∼4 sand formations, with a buried depth of about 2700∼2900 m. It is a beach bar sand deposit with sand and mud interbedding. The sandstone is mostly gray or light gray siltstone, argillaceous siltstone and calcareous siltstone. The mudstone is gray or sandy and mainly gray. The overall structural feature is a monoclinic structure complicated by the fault layer. The average porosity of the reservoir in this block is 14.6%, and the average permeability is 6.2 × 10−3 D. There are many small oil-bearing layers with a longitudinal span of 150 m, the average thickness of the sand body is small, the single-layer protrusion coefficient is large, and the vertical and horizontal heterogeneity is strong. It belongs to the typical low porosity and low permeability beach bar sand reservoir (Shao, 2012).

Water flooding

10.56952/arma-2023-0534

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PETROGRAPHY AND GEOCHEMISTRY OF CENOZOIC SANDSTONES IN THE DUNHUA BASIN, NORTHEAST CHINA: PROVENANCE, DEGREE OF WEATHERING, AND TECTONIC SETTING

Tikhookeanskaya Geologiya (2020)

Fei Hu Zhaojun Liu Qingtao Meng Jinjun Xu

10.30911/0207-4028-2020-39-1-53-69

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Citations (1)

The Bohai Bay Basin: A super basin in eastern China

Second International Meeting for Applied Geoscience & Energy (2022)

Yingchang Cao Guanghui Yuan Jinjun Xu Jingdong Liu

The Bohai Bay Basin in Eastern China is a super basin with estimated petroleum endowment of 202.91 × 108t oil and 31.97 × 1011m3 gas resources. Similar with other super basins, the Bohai Bay Basin has all the components to form the world's super basin, including two sets of high-quality source rocks in combination with stacking of multiple potential reservoirs. The Bohai Bay Basin experienced multi stages of uplift and subsidence since the Paleozoic period, examinations of the development of effective source rocks, reservoirs and hydrocarbon accumulation models are critical for understanding the formation of such a huge hydrocarbon- rich superimposed basin. The two sets of source rocks developed in the Upper Paleozoic Carboniferous-Permian (C-P) and Cenozoic Eocene formations, respectively. The C-P coal measures with coals and mudstones were preserved unevenly in the Bohai Bay Basin, after experiencing different degrees of erosions during the uplift stages. The C-P coal measures experienced three stages of hydrocarbon generation, and the last stage in the late Cenozoic period was effective without subsequent uplift. The Eocene lacustrine mudstones and shales, with thickness of thousands of meters, served as high-quality source rocks and provided most of the hydrocarbons discovered in the Bohai Bay Basin. Multi sets of clastic rocks developed in the Paleozoic, Mesozoic and Cenozoic formations in the Bohai Bay Basin, and formed three types of reservoirs including shallow buried clastic reservoirs with dominating primary pores, moderately- deeply buried clastic reservoirs with dominating primary pores, and moderately-deeply buried clastic reservoirs with dominating secondary pores in the Bohai Bay Basin. With various combination of the source rocks and reservoir rocks after extensive tectonic reconstruction, different types of hydrocarbon accumulations developed orderly in the superimposed basin, and formed the large amount of different hydrocarbon reservoirs in the Bohai Bay Basin. Note: This paper was accepted into the Technical Program but was not presented at IMAGE 2022 in Houston, Texas.

10.1190/image2022-3742256.1

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Sparse-Node Acquisition for Data Fitting Velocity Modelling Via Fwi

83rd EAGE Annual Conference & Exhibition (2022)

Denes Vigh X. Cheng Jinjun Xu Kate Glaccum

Summary Sparse node acquisition has become a standard approach to improve the earth model by the addition of ultra-long offsets. The new designs of node data collections coupled with simultaneous shooting can be deployed on a regional basis covering thousands of square kilometers in a cost-effective manner. In complex geological settings including irregular salt geometry, the salt interpretation has a direct impact on subsalt imaging, however salt interpretation can be quite time-intensive and challenging. Full-waveform inversion (FWI), as a data-driven optimization algorithm with full wavefield modeling, has become one of the essential tools for earth model building. However, its use in the salt tectonic contexts, especially with streamer data collection, is limited since the frequencies acquired are not sufficiently low and the offsets sufficiently long. The recent development of robust objective functions allows the application of FWI workflow on OBN surveys in the deep-water environment in the Gulf of Mexico, to refine the salt geometry and correct the background velocity error in subsalt to uncover the structure configuration in the subsalt that has not been seen before.

10.3997/2214-4609.202210287

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