Numerical simulation on natural gas migration and accumulation in sweet spots of tight reservoir

Zhao, Wen; Zhang, Tao; Jia, Chengzao; Li, Xiangfang; Wu, Keliu; He, Minxia

doi:10.1016/j.jngse.2020.103454

Cited by 22 publications

(17 citation statements)

References 22 publications

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“…In this section, we establish a single sand body geological model (as shown in Fig. 10 ) with a convenient algorithm 3 , and the semi-analytical calculation method of contact angle and interfacial tension proposed in “ Interactions in natural gas–water–rock system ” is embedded into the numerical simulation program. The gas charging and accumulation process will be simulated.…”

Section: Numerical Simulation Set Upmentioning

confidence: 99%

“…1 , there are three main tight gas distribution basins in China, Ordos Basin, Tarim Bain, and Sichuan Basin. Numbers of tight gas-bearing formation have been found in these basins, such as Shanxi Formation (Sulige gas field and Daniudi gas field) in Ordos Basin 3 , Triassic Xujiahe Formation (Guangan gas field and Anyue gas field in Sichuan Basin 4 . Guangan and Anyue gas fields have been successfully developed, Hechuan gas field is in urgent need of development.…”

Section: Introductionmentioning

confidence: 99%

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Effects of interactions in natural gas/water/rock system on hydrocarbon migration and accumulation

Jiang

Zhao

Huang

et al. 2021

Sci Rep

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The study of natural gas accumulation process in tight formation has become the focus of the petroleum industry. One of the priorities is the effects of interactions in natural gas/water/rock system on hydrocarbon migration and accumulation process. On the macroscopic scale, we investigate the interactions in natural gas/water/rock system by formation fluorescence test and production data analysis. One the microscopic scale, the mechanisms are revealed by mathematical analysis and experimental methods considering the variation of geological temperature and pressure. The effects of interactions in natural gas/water/rock system are also simulated by numerical simulation. The results are visualized and quantified. A novel semi-analytical method based on a physical experiment is proposed to calculate the temperature- and pressure-dependent contact angle and interface tension which reflect the interactions in the natural gas–water–rock system. This semi-analytical is embedded in the numerical simulation during the simulation of the natural gas charging process. The results indicate that with the increase of geological temperature and pressure, the contact angle will increase and the interface tension between natural gas and water will decrease. The capillary resistance in the formation will be reduced. Since the decrease of capillary resistance, the natural gas can be charged into smaller pores, so that the actual charging threshold is lower than the one originally obtained under present reservoir conditions. After considering the temperature and pressure during the accumulation process, some sand bodies that were thought not to be charged may have natural gas accumulate.

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Section: Numerical Simulation Set Upmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Effects of interactions in natural gas/water/rock system on hydrocarbon migration and accumulation

Jiang

Zhao

Huang

et al. 2021

Sci Rep

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“…Conventional hydrocarbon resources in the north of Songliao Basin have supported the efficient exploration and development of the Daqing oilfield for more than 60 years, which has made great contributions to Chinese energy security and Chinese economic development [8]. However, after decades of exploration and development in the Daqing oilfield, the remaining resources are hard to develop, as the residual reserves are of poor quality and the recovery rate is low [9,10]. Therefore, new areas of reserve resources are urgently needed to ensure the revitalization and development of Daqing Oilfield.…”

Section: Introductionmentioning

confidence: 99%

Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation

et al. 2021

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Pore network modeling based on digital rock is employed to evaluate the mobility of shale oil in Qingshankou Formation, Songliao Basin, China. Computerized tomography technology is adopted in this work to reconstruct the digital rock of shale core. The pore network model is generated based on the computerized tomography data. We simulate the dynamics of fluid flow in a pore network model to evaluate the mobility of fluid in shale formation. The results show that the relative permeability of oil phase increases slowly in the initial stage of the displacement process, which is mainly caused by the poor continuity of the oil phase. In the later stages, with the increase in the oil phase continuity, the range of relative permeability increases. With the increase of organic matter content, the permeability of the water phase remains unchanged at low water saturation, but gradually increases at high water saturation. At the same time, it can be seen that, with the increase in organic matter content, the isosmotic point of the oil–water phase permeability shifts to the left, indicating that the wettability to water phase gradually weakens.

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“…Multiple biomarkers can be well considered with the methods of chromatograms or homologous series distribution patterns. Since only a few samples can be tested, the geochemical characteristics of the oil system cannot be well considered, which will improve the uncertainties in oil-source correlation and cannot meet the accuracy needed in oil-source correlation [11,12]. To overcome the above limitations, researchers adopt multivariate statistical analysis methods in the oil-source correlation, which can process multiple geochemical parameters and large numbers of samples simultaneously [13,14].…”

Section: Introductionmentioning

confidence: 99%

Geochemical Characteristics and Oil Source Correlation of Minfeng Area, Dongying Depression, China

Jiang

Zhao

et al. 2021

Geofluids

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The identification of the oil-source correlation plays a significant role in petroleum exploration and development. In this study, we identify the oil-source correlation by a hierarchical cluster analysis method combined with traditional methods. The results shed light on the oil-source correlation in Minfeng area and revealed the oil migration and accumulation process. The crude oil in different structural belts and different horizons has different geochemical characteristics. According to the four types of crude oil and their planner distribution, it was considered that the crude oil mainly migrates along with favorable sand bodies and unconformity surfaces in the lateral direction and then charged and accumulated in the glutenite of Sha3 and Sha4 members since the area from sag to Yan Jia Oil and the gas field was lacking of oil source faults. Further analysis shows that the traps of fault blocks in Yong’anzhen are formed in the same phase, while the crude oil generated in the early stage is charged and accumulated in the fault block of the near source. Along with increasing of the buried depth of source rocks, the overlying source rocks gradually entered into the hydrocarbon generation phase, when crude oil started to charge in the fault blocks farther away.

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Numerical simulation on natural gas migration and accumulation in sweet spots of tight reservoir

Cited by 22 publications

References 22 publications

Effects of interactions in natural gas/water/rock system on hydrocarbon migration and accumulation

Effects of interactions in natural gas/water/rock system on hydrocarbon migration and accumulation

Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation

Geochemical Characteristics and Oil Source Correlation of Minfeng Area, Dongying Depression, China

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