Crude oils from five oil and/or gas fields and five wells in the region of the Higashiyama oil field, Niigata Prefecture, Japan, are divided into three groups (A, B, C) based on their geochemical characteristics:

Group A : the Higashiyama and Nagaoka oils, which are Niitsu-type with relatively low maturity.

Group B : the Mitsuke and Ohmo oils, which are Niitsu-type with relatively high maturity, and oils from the Shimodori and Shin-nishinagaoka wells.

Group C : the Nishi-nagaoka oil, and oil from the Kurosaka well, which are Kubiki-type. Similar oils include those from the Teradomari Formation in the Katakai gas field, including the Asahihara well.

Oils of groups A and B were probably generated in a depression between the Higashiyama and Mitsuke fields, as inferred from the geographic distribution and cumulative production of oil fields, the distribution of oil reservoirs in the Higashiyama field, and other factors. The oil maturity indicates that the Higashiyama oil migrated before the Mitsuke and Ohmo oils.

The Nishi-nagaoka oil was probably generated within the same depression as oils from the Katakai field, whose place may be located east to the Katakai field, given the geologic structure in the field.

This paper shows that geochemical analysis of crude oils stored for a long time provides valuable information on the classification and maturity of oils and the source rock.

To better understand the petrophysical characters of the Marcellus Shale and to identify pore system that contributes to the gas production, we conducted a series of petrophysical measurements. A positive correlation between porosity and total organic carbon (TOC) was observed in samples from the lowermost Marcellus Shale, whereas a different relationship was observed in samples from the lower parts of Marcellus Shale. These two geological units showed a difference in pore size distribution, which was obtained from mercury intrusion capillary pressure (MICP) test. In addition to this, detailed scanning electron microscope (SEM) observations of samples from the lower and lowermost parts of the Marcellus Shale reveal that the petrophysical properties and pore systems in these parts differ. In both parts, an abundant existence of nano pores is supported from N₂ adsorption test and these pores would play an important role in the gas production.

The Amu Darya Basin is a proven hydrocarbon-bearing basin extending from Turkmenistan to northern Afghanistan. A number of fields have been discovered in the Afghan side of the basin: The Jangal-e-Kalan, Yatimtaq, Khwaja Gogerdak and Khwaja Bulan gas fields in the northwest, and Angot oil field in the southeast. There is however a limited number of researches on the petroleum system of the area, remaining it poorly understood.

One-dimensional basin modeling was conducted to reconstruct the burial and thermal history, and simulate hydrocarbon generation and expulsion in the Afghan side of the Amu Darya Basin. The principal objectives were to estimate the maturity of the Lower and Middle Jurassic source rocks, and to determine the kitchen areas and timing of hydrocarbon generation and expulsion.

This study was carried out along a published geological cross section which traverses the basin in NW-SE direction. The data obtained from actual wells were used to calibrate modeling parameters. Three pseudo wells were then created at synclines along the section for simulating hydrocarbon generation and expulsion in the potential kitchen areas.

The major finding of this study is that the maturity of Lower and Middle Jurassic source rocks varies in different parts of the basin. At the northwest syncline (pseudo well-1), the source has reached the gas window in Cretaceous, and has expelled gas since then. The area is therefore most likely the kitchen for the neighboring gas fields. On the other hand, the source in the southeastern syncline (pseudo well-3) is now at peak to late oil window, and is expelling oil. The Angot oil must be charged from this syncline. The source in the middle part (pseudo well-2) is also in its late oil window. The difference from pseudo well-3 is that it has undergone uplifting since Paleogene, indicating hydrocarbon expulsion has ceased before trap formation.

Effective competency development is a key challenge for oil producing countries. “Bespoke” concept training program was developed with a hypothetical reservoir model, and successfully implemented for young national professionals of Azerbaijan.