Role of Organic Matter, Mineral, and Rock Fabric in the Full-Scale Pore and Fracture Network Development in the Mixed Lacustrine Source Rock System

Abstract

The mixed deposition constitutes the external clastic, intrabasinal, and pyroclastic components in both marine and lacustrine environments. The finegrained mixed lacustrine source rocks are rich in organic matter and present good unconventional energy resources. However, the mixed lacustrine source rock systems have extremely low permeabilities and need hydraulic fracturing to stimulate oil from the complex nanoscale matrix. The role of rock fabric, organic matter, and mineral compositions in full-scale pore structures is still unclear, especially for the source rock from a mixed sedimentary environment. This restricts sweet spot identification. Here, we use three groups of Permian Lucaogou source rock samples with fine laminated, thick laminated, and massive rock fabric to investigate the relationship between rock fabric, organic matter, and pore structure using a combination of mineralogy, organic geochemistry, low-pressure nitrogen adsorption, micro-CT, and mercury injection capillary pressure data. The results indicate that the Lucaogou source rocks mainly contain type I and type II kerogen and show good to excellent hydrocarbon generation potential. The source rock was deposited in a mixed environment with high contents of carbonate and less siliceous minerals, showing good frackability. The mineralogy-based ternary classification shows that the source rock mainly belongs to high total organic carbon (TOC > 4%) mixed carbonate mudstone and high TOC mixed mudstone. For mixed lacustrine source rock, the full-scale pore-fracture distribution shows that the average percentage values of pore volume for micropores (<10 nm), transitional pores (10−100 nm), mesopores (100−1000 nm), and macropores (fracture) (>1000 nm) are 11.14, 21.62, 10.77, and 56.47%, respectively. However, the average percentage values of pore surface area for the abovementioned pores are 62.45, 30.45, 5.47, and 1.63%, respectively. Both quartz and terrigenous clast present a weak-medium unimodal correlation with the TOC content. Both terrigenous clast and clay minerals control the source rock hydrocarbon generation potential. The carbonate and terrigenous clast mineral content play a significant role in micropores and transitional pores, while the clay mineral presents a negative impact on macropore development. The effect of rock fabric on shale oil potential is negligible compared with organic matter abundance. Shales with thick parallel laminae and medium TOC (2% < TOC < 4%) possess favorable shale oil potential.

Geological Features, Paleosedimentary Environment, and Organic Matter Accumulation Mechanisms of the Lacustrine Shale Oil System: A Case Study of the Jurassic Dongyuemiao Member in the Sichuan Basin

“…We adopted the pore size classification proposed by Yang et al [58] specifically for lacustrine shale, as the pore sizes observed in the Dongyuemiao shale varied significantly. The classification includes micropores (1-10 nm), transitional pores (10-100 nm), mesopores (100-1000 nm), and macropores (more than 1000 nm).…”

Novel Method for the Classification of Shale Oil Reservoirs Associated with Mobility: Inspiration from Gas Adsorption and Multiple Isothermal Stage Pyrolysis

“…Moreover, it can be further divided into the III oil bed, clay interlayer bed, II oil bed, I oil bed, and gypsolyte bed from bottom to top. The II oil bed, with a thickness of ∼100 m, is one of the predominant exploration systems for shale oil in the basin. , …”

“…The II oil bed, with a thickness of ∼100 m, is one of the predominant exploration systems for shale oil in the basin. 25,51…”

“…TP = Transitional pore; MeP = Mesopore; Macrop = Macropore. Reproduced with permission from ref , copyright 2017 Elsevier, ref , copyright 2022 Elsevier, ref , copyright 2022 American Chemical Society, and ref , copyright 2022 American Chemical Society.…”

Exploration of Oil/Water/Gas Occurrence State in Shale Reservoir by Molecular Dynamics Simulation

“…Studies have revealed that the molecular structure of shale oil generated in its early stages is similar to that of the source rock [12]. The resemblance leads to a strong adsorption affinity between them [13,14], for which shale oil typically adsorbs on the surfaces of microfractures in organic and inorganic pores as oil film [15]. As the generation for hydrocarbon increases, the amount of shale oil may exceed the maximum capacity of Energies 2023, 16, 7253 2 of 14 current sites and migrate into larger adjacent pores and microcracks [16].…”