Geofluids in Deep Sedimentary Basins and Their Significance for Petroleum Accumulation

Luo, Xiaorong; Jin, Zhijun; Liu, Keyu; Zhang, Shuichang

doi:10.1155/2017/3571359

Cited by 3 publications

(1 citation statement)

References 15 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The type of hydrocarbon phase in the reservoir not only affects resource evaluation, field development, and facilities design but also has different economic benefits. ,, In addition, there are differences in the physical properties (e.g., density, viscosity, interfacial tension) of hydrocarbons with different phase states, resulting in significant differences in the dynamics of hydrocarbon charging, migration, and accumulation. − It is of great importance for understanding the current compositional distributions in the reservoir, the mechanism of the migration and accumulation of hydrocarbons in ultradeep reservoirs, and explaining the distribution of hydrocarbons in different phase states in a basin. − …”

Section: Introductionmentioning

confidence: 99%

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Xu,

Lei,

Zhang

et al. 2023

Energy Fuels

View full text Add to dashboard Cite

A large amount of oil and gas has been discovered in the ultradeep reservoirs in the Shawan Sag, Junggar Basin. However, the hydrocarbon phases in ultradeep reservoirs are complex, and the controlling factors and evolution have not been studied, which are important for exploration and development. This study determined the hydrocarbon phase states of the reservoirs in the Upper Wuerhe Formation (P3w) of Well Zheng 10 in the Shawan Sag via hydrocarbon components and a pressure–volume–temperature (PVT) phase diagram. We used 1D basin modeling to simulate the thermal maturity of the Lower Wuerhe (P2w) source rock, components of generated hydrocarbons, reservoir temperature and pressure, and hydrocarbon phase. The results show that the hydrocarbons in the P3w reservoir are secondary condensate gas. The source rock began to enter the threshold of hydrocarbon generation at the end of the Late Triassic, and the thermal maturity (Easy Ro%) of the P2w source rock in the P3w reservoir fetch area is approximately 1.5% at present. The reservoir experienced multiple periods of hydrocarbon charging and phase evolution. During the Late Triassic to the early Late Jurassic and the late Early Cretaceous to the Late Cretaceous, the hydrocarbons in the P3w reservoir were liquid. Since the Miocene, a large amount of gas has migrated to the P3w reservoir, leading to gas invasion, which is the key to the formation of a condensate gas reservoir. The hydrocarbons changed from liquid to condensate gas due to the increasing gas–oil ratio and reservoir temperature. This study provides a quantitative method to reconstruct the phase evolution process and establishes an accumulation model of condensate gas reservoirs.

show abstract

Section: Introductionmentioning

confidence: 99%

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Xu,

Lei,

Zhang

et al. 2023

Energy Fuels

View full text Add to dashboard Cite

show abstract

Deep fluids and their role in hydrocarbon migration and oil deposit formation exemplified by supercritical СO₂

Лифшиц

2021

Earth and Environmental Science Transactions of the Royal Society of Edinburgh

View full text Add to dashboard Cite

Hydrocarbon migration mechanism into a reservoir is one of the most controversial in oil and gas geology. The research aimed to study the effect of supercritical carbon dioxide (СО2) on the permeability of sedimentary rocks (carbonates, argillite, oil shale), which was assessed by the yield of chloroform extracts and gas permeability (carbonate, argillite) before and after the treatment of rocks with supercritical СО2. An increase in the permeability of dense potentially oil-source rocks has been noted, which is explained by the dissolution of carbonates to bicarbonates due to the high chemical activity of supercritical СО2 and water dissolved in it. Similarly, in geological processes, the introduction of deep supercritical fluid into sedimentary rocks can increase the permeability and, possibly, the porosity of rocks, which will facilitate the primary migration of hydrocarbons and improve the reservoir properties of the rocks. The considered mechanism of hydrocarbon migration in the flow of deep supercritical fluid makes it possible to revise the time and duration of the formation of gas–oil deposits decreasingly, as well as to explain features in the formation of various sources of hydrocarbons and observed inflow of oil into operating and exhausted wells.

show abstract

Main controlling factors of natural fractures in tight reservoirs of the lucaogou formation in the jimsar sag, Xinjiang, China

et al. 2023

View full text Add to dashboard Cite

Natural fractures act as critical flow channels and reservoir space in the Lucaogou Formation tight reservoir of the Jimsar Sag. It is essential to identify the main controlling factors of natural fractures in order to achieve efficient development of tight oil in this area. There are mainly three types of natural fractures, including tectonic fractures, diagenetic fractures, and abnormal overpressure-induced fractures. Diagenetic fractures are predominantly bedding seams. The fracture development is affected by multiple factors including brittle minerals, lithology, tectonic stress, bed thickness, and total organic carbon (TOC). Large tectonic stress, smaller bed thickness, and higher total organic carbon are all favorable for the development of tectonic fractures and bedding seams. The controls of brittle minerals and lithology on fracture development are different for tectonic fractures and bedding seams. Specifically, carbonate minerals stimulate the tectonic fracture development, while brittle minerals have no control over the bedding seam development; tectonic fractures are most developed in the dolomitic rocks, while bedding seams are most developed in the argillaceous rocks. The calculated fracture density variation coefficients reveal that tectonic stress and brittle minerals are the main controlling factors of tectonic fracture development; total organic carbon and lithology are the main control factors of bedding seam development.

show abstract

Geofluids in Deep Sedimentary Basins and Their Significance for Petroleum Accumulation

Cited by 3 publications

References 15 publications

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Deep fluids and their role in hydrocarbon migration and oil deposit formation exemplified by supercritical СO₂

Main controlling factors of natural fractures in tight reservoirs of the lucaogou formation in the jimsar sag, Xinjiang, China

Contact Info

Product

Resources

About

Geofluids in Deep Sedimentary Basins and Their Significance for Petroleum Accumulation

Cited by 3 publications

References 15 publications

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Deep fluids and their role in hydrocarbon migration and oil deposit formation exemplified by supercritical СO2

Main controlling factors of natural fractures in tight reservoirs of the lucaogou formation in the jimsar sag, Xinjiang, China

Contact Info

Product

Resources

About

Deep fluids and their role in hydrocarbon migration and oil deposit formation exemplified by supercritical СO₂