Sweet spot evaluation and exploration practice of lacustrine shale oil of the second member of Kongdian Formation in Cangdong sag, Bohai Bay Basin

The in situ stress field and microscale controlling factors in the Ordos Basin, central China

Unlike liquid-rich hydrocarbons in marine shale systems in North America, the Triassic Yanchang oil is preserved in tight sandstone reservoirs deposited in a lacustrine setting. The tight reservoir covers an area of 30,000 km2 (11,600 mi2) and is characterized by ultralow permeability (∼0.001–1.00 md [∼0.001 × 10−3–1.00 × 10−3 μm2]), a low subsurface pressure coefficient (0.6–0.8), and low single-well yield (several tons [10–40 bbl] to >10 tons [>70 bbl] per day). The reservoir also features a high content of quartz, feldspar, and carbonate (averaging 70%–80%) and low crude oil density of 0.84 g/cm3 (36.5° API) with an oil saturation of approximately 60%–80%. For the first time, this study employs the assessment of petroleum in-place resources based on the genesis and statistics predicting method (GSPM) and estimated ultimate recovery method for the tight oil in the Ordos Basin. The advantage of GSPM over previously reported methodologies is the suitable combination of genetic and statistical methods to estimate proximally sourced tight oil. The results show that the total in-place resource potential of the investigated tight oil is approximately 42.26 × 108 t (∼295.82 × 108 bbl), with an average abundance of 15 × 104 t/km2 (99 × 104 bbl/mi2). The recoverable resources for the 50% probability of the Chang 7 tight oil accumulation is 3.11 × 108 t (21.77 × 108 bbl) in the Ordos Basin. The top two grades of the Chang 7 tight oil core area cover the total area of three layers comprising 12,745 km2 (4921 mi2), with 22.51 × 108 t (157.57 × 108 bbl) of in situ resources. Furthermore, the four most promising zones have been identified.

Resource potential and core area prediction of lacustrine tight oil: The Triassic Yanchang Formation in Ordos Basin, China

Differences in source kitchens for lacustrine in-source and out-of-source hydrocarbon accumulations

Abstract During the production from shale oil formations, the produced water has been dedicated to different procedures such as chemical enhanced oil recoveries, drilling mud making (e.g., for various purposes of lubrication and cooling) and hydraulic fracturing. One of the main challenges of wastewater treatment corresponds to (TDS) total dissolved solids. To measure the required water needed for different processes, it is necessary to proceed with every step saving and then make an average to calculate the required freshwater. In this regard, we have selected five different oil wells with the same rock and reservoir characteristics. SOW#3 has the highest rate of treatment (26%) and SOW#1 has the minimum treated wastewater during hydraulic fracturing processes. It corresponds to the large volume of solid and oil particles, which remained in the treatment devices. However, it is observed that SOW#1 has the highest rate of treatment (32%) and SOW#4 has the minimum treated wastewater (14%) in chemical enhanced oil recovery methods. On the other hand, SOW#3 has the highest rate of treatment (27%) and SOW#5 has the minimum treated wastewater from drilling mud preparation and other well facilities. It is observed that SOW#1 has the highest rate of treatment (27%) and SOW#5 has the minimum saving water during hydraulic fracturing processes, SOW#1 has the highest rate of treatment (38%) and SOW#4 has the minimum saving water (9%). 

/pdf/sustainable-wastewater-management-from-shale-oil-production-1u3rz0mt.pdf

Sustainable wastewater management from shale oil production wells: emerging opportunities and barriers

Geologic significance and optimization technique of sweet spots in unconventional shale systems

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Geologic significance and optimization technique of sweet spots in unconventional shale systems