Study on Organic Identification of Black Shale in Bokor Formation, Kampot Province, Cambodia
Ratha Heng,
Sopheap Pech,
Sreymean Sio,
Chandoeun Eng,
Chanmoly Or
Issue:
Volume 10, Issue 4, July 2022
Pages:
90-96
Received:
1 August 2022
Accepted:
24 August 2022
Published:
16 September 2022
DOI:
10.11648/j.ogce.20221004.11
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Abstract: Organic petrology is the key study to identify the favorable geological condition of black shale as a hydrocarbon source rock. The study aims to identify the organic matter types in the black shale of Bokor Formation, Kampot province. Three outcrop cross-sections (Phnom Khley, Phnom Chakrey, and Phnom Monprey), which extend from the West to the East of Kampot province, were investigated for stratigraphic sequences, sedimentary structures/textures, fossil contents through fieldwork observation. Rock sampling was conducted to performed polish pellet for organic petrology. The result demonstrated that the western part consisted of repeated sequences of thin laminated shale layers interbedded with massive sandstone layers. In the eastern part, the shale layers are continually deposited as a thick bedding with fossils of syringopora, crinoid, and foraminifera, which indicates a low energy flow environment during sediment deposition. Organic petrologic analysis in shale samples revealed that alginate and bituminite were dominantly found shale samples in the Phnom Khley section, whereas macrinite and vitrinite were observed in Phnom Monprey and Phnom Chakrey, respectively. The presence of alginate, bituminite, and macrinite, suggest a potential for hydrocarbon source rock. The maceral types, such as alginite, bituminite, micrinite, and vitrinite, indicate deposition in periodically oxygenated bottom water and a sulfidic marine water environment. Based on the existing macerals and cubic pyrite that presented in the collected samples, those source rocks are suggested as thermally mature petroleum source rock.
Abstract: Organic petrology is the key study to identify the favorable geological condition of black shale as a hydrocarbon source rock. The study aims to identify the organic matter types in the black shale of Bokor Formation, Kampot province. Three outcrop cross-sections (Phnom Khley, Phnom Chakrey, and Phnom Monprey), which extend from the West to the Eas...
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Determination of Sorption Capacity for Different Sorbates of Adsorbents Used for Dearomatization and Deparaffinization of Motor Oils
Safarov Jasur,
Khayitov Ruslan
Issue:
Volume 10, Issue 4, July 2022
Pages:
97-100
Received:
18 April 2022
Accepted:
15 September 2022
Published:
27 September 2022
DOI:
10.11648/j.ogce.20221004.12
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Abstract: The sorption capacity of the selected adsorbents was determined - silica gel CSL (coarse-pored silica gel lump) and synthetic zeolite CaA according to the standards of aromatic and n-paraffin hydrocarbons using the cryoscopic method. The amount of adsorbed substance in weight percent for each portion of the filtrate is converted into grams, summed up and referred to 100 g of the adsorbent. After that, the silica gel was washed with distilled water until the reaction to the Cl– ion was negative, unloaded onto filtered paper, and left to dry in the open air. The solution was passed in a chromatographic column through an adsorbent. The amount of adsorbed substance A was calculated. Type A synthetic zeolites include zeolites with radii: KA (0,3 nm), NaA (0,4 nm) and CaA (0,49 nm). CaA zeolite adsorbs hydrocarbons and alcohols of normal structure only (regardless of the chain length) due to the size of the input window corresponding to the size of their critical diameters The synthesized zeolites are powders and in order to use them under dynamic conditions, they are granulated with the addition of a binder, usually natural clays, and molded into tablets, cylinders, or balls. The sorption capacity of the synthetic zeolite CaA for n-hexane from the liquid phase under dynamic conditions is given. As can be seen from the given data, benzene is practically not adsorbed by CaA zeolite, but is adsorbed by silica gel. Moreover, CSL silica gel activated with hydrochloric acid has a higher capacity.
Abstract: The sorption capacity of the selected adsorbents was determined - silica gel CSL (coarse-pored silica gel lump) and synthetic zeolite CaA according to the standards of aromatic and n-paraffin hydrocarbons using the cryoscopic method. The amount of adsorbed substance in weight percent for each portion of the filtrate is converted into grams, summed ...
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Investigation and Optimization of Infill Well Spacing Using Geomechanical and Simulation Studies on Shale Gas Reservoir to Maximize Performance and Financial Return
Haijun Fan,
Mamoudou Kouma,
Najmudeen Sibaweihi
Issue:
Volume 10, Issue 4, July 2022
Pages:
101-114
Received:
4 September 2022
Accepted:
19 September 2022
Published:
27 September 2022
DOI:
10.11648/j.ogce.20221004.13
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Abstract: The process of developing shale reservoirs has proceeded to the point where new wells are drilled in close proximity to the "parent" well. These new wells pose a problem for operators because they can lead to complicated interactions between wells, reducing the performance of either one or both of the parent and child wells. A successful field development near producing wells requires careful consideration of the distance between wells to minimize the volume of unproduced gas and loss of revenue. In the oil and gas industry, appropriate horizontal well spacing is often determined by a combination of geological modeling with reservoir simulation. The goal of this research is to identify the best field development approach that maximizes both gas production and financial return. In the course of our study, a shale gas reservoir is modeled using flow simulation-based reservoir simulation, to carry out a sensitivity analysis that will help optimize shale gas production in the future, and we took into account the adsorption/desorption phenomenon, the geomechanics effect coupled with the heterogeneity property, which are very characteristic of real shale gas reservoirs. For 20 years of gas production, we sought first to find optimal well numbers and geometries scenarios. Then we decided to intelligently down space the horizontal wells with multiple hydraulic fracturing stages by adjusting the distance at different completion times between parent well(s) and child well(s). We investigated both lateral and vertical well spacing in order to achieve the highest possible volume of gas production and amount of net present value (NPV). According to the findings of our simulations, ten wells with aligned well geometry provide the most economic benefit for the optimization strategy. In order to maximize the gas recovery, the lateral well spacing needs to be greatly increased, and the vertical well spacing needs to be decreased to a point where more gas can be produced from each well. In addition, the findings of the economic analysis indicated that increasing the distance between wells may result in more great financial value for the lateral wells spacing. However, all wells must be drilled in the same pay zone for vertical well spacing to provide a better economic return. In spite of the fact that the outcomes of our work depend on the selected asset, they provide a significant illustration for determining the optimal spacing between hydraulically fractured horizontal wells for shale gas reservoirs.
Abstract: The process of developing shale reservoirs has proceeded to the point where new wells are drilled in close proximity to the "parent" well. These new wells pose a problem for operators because they can lead to complicated interactions between wells, reducing the performance of either one or both of the parent and child wells. A successful field deve...
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