Hydrocarbon source potential of Eocene-Miocene sequence of Western Sabah,Malaysia     

《Marine and Petroleum Geology》2017

An evaluation of the petroleum generating potential of onshore Eocene-Miocene sequences of Western Sabah, Malaysia was performed based on organic petrological and geochemical methods. The sequences analysed are the Belait, Meligan, Temburong and West Crocker formations of western Sabah. The Belait Formation which is Stage IV equivalent in the offshore represents one of the major source rock/reservoirs of the petroleum-bearing Sabah Basin. The Eocene-Early Miocene West Crocker and Temburong formations are deepwater turbidites whilst the Miocene Meligan and Belait formations are shallow marine fluvio-deltaic deposits. The vitrinite reflectance and pyrolysis T_max values show that the Belait samples are generally immature for hydrocarbon generation, whereas the Meligan, Temburong and West Crocker samples are in the mature to late maturity stage of hydrocarbon generation. The overall bulk source rock properties of the Belait and Meligan show fair to good petroleum source rock potential with TOC more than 1 wt %, hydrocarbon yield in the range of 400–1300 ppm and moderately high HI for many of the samples. Most of the samples representing the Temburong and West Crocker formations have TOC less than 1 wt% and have no to fair hydrocarbon generating potential. Interestingly, the samples collected in the West Crocker Formation characterized by slump deposits (MTD) have TOC>2 and possess good to excellent hydrocarbon generating potential. The organic matter present in all of the studied formations is mainly of terrigenous origin based on the abundance of woody plant materials observed under the microscope. Consequently, the analysed sequences are predominantly gas prone, dominated by Type III and Type III-IV kerogen except for minor occurrence of mixed oil-gas prone Type II-III kerogen in the Belait Formation and in the slump mass transport deposits (MTD) of the West Crocker Formation.  相似文献   

The transformation of γ Fe2O3 to α Fe2O3: thermal activation and the effect of elevated pressure     

《Physics of the Earth and Planetary Interiors》1999,110(1-2):43-50

The transformation of acicular γ Fe₂O₃ particles to α Fe₂O₃ has been monitored using magnetic properties as a proxy for γ Fe₂O₃ concentration during the inversion process. The transformation is thermally activated, the height of the barrier opposing inversion being 3.7 eV at atmospheric pressure and 0.5 eV at a pressure of about 100 MPa. The barrier arises from the combination of a term representing the reduction in lattice energy in an inverted region, and the strain energy associated with the interface between the inverted and non-inverted phases. The sensitivity of the inversion process to pressure can be understood in terms of the dependence of these energy terms, and the energy barrier, on interatomic spacing. Extrapolation of these laboratory data to the conditions of the submarine crust at Site 504B of the Deep Sea Drilling Project is consistent with the inferred magnetic mineralogy of the recovered material.  相似文献   

Retraction Note to: Adaptive neuro-fuzzy prediction of the optimum parameters of protective spur dike     

Basser  Hossein  Shamshirband  Shahaboddin  Petković  Dalibor  Karami  Hojat  Akib  Shatirah  Jahangirzadeh  Afshin 《Natural Hazards》2020,103(2):2629-2630

Natural Hazards - The Editors-in-Chief have retracted this article because validity of the content of this article cannot be verified.  相似文献   

Editorial Board     

《Tectonophysics》1996,257(1):ii-iii

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Hydrothermal hydrocarbon gases: 2, Application in the East African Rift System     

《Applied Geochemistry》1998,13(7):825-840

Hydrocarbon gases are ubiquitous in the hydrothermal systems of the East African Rift System (EARS), though often found at very low concentrations in the ‘volcanic’ eastern branch as compared to the ‘sedimentary’ western branch. Study of the chemical and isotopic compositions of these hydrocarbons from sites in Kenya, Ethiopia, Djibouti and Uganda reveals considerable homogeneity over hundreds of km of the various rift units. Consideration of C and He isotopic evidence points to a predominantly crustal thermogenic origin for the hydrocarbons, there being no evidence of mantle inputs in either the MORB or ‘hotspot’ sectors of the EARS. Temperature information from geothermal wells has been utilised to investigate the relationship between reservoir temperatures and ratios of CH₄ to C₂H₆. The general C₁/C₂ geothermometric relationship proposed in Part 1 of this study holds reasonably well, and is shown to give results equal to or better than the ‘inorganic’ gas geothermometers presently in use, both in the wellfields and undeveloped high-enthalpy geothermal areas. Results from low-enthalpy hot spring systems are less well correlated with apparent deep temperatures, but consistent with data from similar systems elsewhere in the world.  相似文献   

Organic acids from source rock maturation: generation potentials,transport mechanisms and relevance for mineral diagenesis     

《Applied Geochemistry》1993,8(4):325-337

Hydrous pyrolysis has been used to simulate maturation of source rocks with respect to the generation of organic acids and CO₂. The results from pyrolysis experiments on eight different source rocks at this laboratory are given and compared with published data. The investigation show levels of generation for acetic acid equivalent to 0.2–1.2% of the TOC of the source rock and total acids at a level of 1–2% of the TOC. The generated CO₂ is equivalent to 1–10% of the TOC. The relative amounts of CO₂ and organic acids and the maturity dependence of the yield are a function of the source rock type.The amounts of acids generated are sufficient to give significant concentrations in the fluid phases of the source rock and, after migration, in adjacent rocks. Reaction and equilibration with minerals will occur at the first contact, which in most cases will be in or close to the source rock. The organic acids may initially be dissolved in the oil phase, but their high aqueous solubilities will make them diffuse rapidly out of the oil phase and into the surrounding water phase as soon as the oil has migrated into porous carrier beds. The migration of the petroleum phase is driven by buoyancy and there is no equivalent drive for water flow from source rock to reservoir. If the distance between source and reservoir s large, the organic acids found in the reservoir formation waters must therefore have been transported in the oil phase or generated in situ from emplaced oil or disseminated kerogen. The high water solubility of the acids will, however, limit the distances they can be transported in the oil phase. In situ generation in the reservoir must therefore be seriously considered.  相似文献