1. Source rock potential assessment of the Huai Hin Lat Formation, Sap Phlu Basin, Nakhon Ratchasima Province, northeastern Thailand.
- Author
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Arsairai, Boonnarong, Feng, Qinglai, Chonglakmani, Chongpan, and Glumglomjit, Sakchai
- Subjects
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NATURAL gas pipelines , *ANALYTICAL geochemistry , *VITRINITE , *MACERAL , *KEROGEN - Abstract
The Huai Hin Lat Formation has a high-potential resource, and the Ban Nong Sai part was researched and sampled. To achieve this goal, petrographic analysis (kerogen types), geochemical analysis (total organic carbon content, TOC), vitrinite reflectance (Ro), and Rock–Eval (RE) pyrolysis were carried out in this study. According to the findings, types II, III, and IV were identified using a modified Van-Krevelen diagram because the higher mature source rock showing hydrogen index (HI) and oxygen index (OI) are continuously depleted and raised. However, microscopic observation describes macerals as primarily sapropelic amorphinite, therefore, type I is important. The TOC was determined to be between 1.90% and 7.06%, which is considered very good to excellent. The original total organic carbon (TOCo) was decided to use its maceral components to determine how to convert extremely mature TOC to TOCo. It varies between 5.13% and 10.74% and reaches a maximum of 57.21% which is comparable to TOC. At 0.82%–1.04%, 443–451 °C, 0.50%–38.10%, and 69.00%–99.59% are the vitrinite reflectance (Ro), maximum temperature (Tmax), production index (PI), and transformation ratio (TR), respectively. Late peak maturity refers to a mixture of oil and gas, whereas most TR ratios refer to the main gas phase. Similarly, the petroleum residual shows no indication of gas trapped at a volume of 6309.50 mcf/ac-ft. In summary, source rock potential was assessed within a suitable risk range defined by Tmax (445.70 °C), Ro (0.91%), TR (90.63%), TOC (8.15%), shale thickness (46 m), and kerogen type (type I). [ABSTRACT FROM AUTHOR]
- Published
- 2023
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