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The present study has clearly demonstrated that seeding a petroleum hydrocarbon polluted sea water with a halotolerantPseudomonas aeruginosaAsph2 and corn steep liquor as a cheap and readily available source of nutrients significantly enhances the progress of biodegradation BD of petroleum hydrocarbon pollutants. There was a statistically high significant difference between natural weathering NW and both bioaugmentation BA (p = 2.92e-14) and biostimulation BS (p = 3.56e-13) at 95% confidence interval (α = 0.05). BA significantly improved the efficiency of total petroleum hydrocarbon TPH and the recalcitrant asphaltene degradation by ≈ 23 and 17% compared to BS process (p = 2.0693e-5 andp = 1.4e-3, respectively). The BD of biomarkers; pristane Pr, phytane Ph, and terpanes were very apparent. The BD of C28 tricyclic terpane, C27 13β, 17α- diasterane (20S), and C30 17α, 21β-hopane were higher than that of C35 17α,21β-homohopane. The BD of C27 18α(H)-22,29,30-trisnorneohopane (Ts) was higher than that of C27 17α(H)-22,29,30-trisnorhopane (Tm). The BD of sterane was higher than that of hopane. C30 18α-Oleanane was more resistant to degradation than other compounds. [ABSTRACT FROM PUBLISHER]

Ten core samples representing the subsurface formation of Sidi Salem well No. 1, in the onshore Nile Delta, Egypt. The samples were subjected to comprehensive organic geochemical studies (such as rock-eval pyrolysis, gas chromatograph [GC] and gas chromatography-mass spectrometry [GC-MS]) aiming to evaluate potential source rocks, organic matters types, depositional environments, and maturation. The results revealed that the source rocks in the drilled sections are marginally mature to mature zone and have fair to good potential for generating oil and gas. These rocks are dominated by organic matter derived mainly from mixed organic matters (marine and terrestrial) with contributions from algae and bacteria deposited under anoxic to suboxic saline environments. [ABSTRACT FROM AUTHOR]

This paper introduces a new modeless modular compensating strategy to extract and mitigate power-quality (PQ) disturbances. The main advantage of this strategy is that it does not require any model or state-space formulation to extract the disturbances, such as the other commonly used state-space techniques. In addition, it is very simple for practical implementation compared to the time-domain and frequency-domain methods. The proposed strategy depends on recursive implementation of the Wiener filtering theory. The suggested strategy is validated by digital simulation results on the most common stationary and transient PQ problems. [ABSTRACT FROM AUTHOR]

Seven representative oil show samples from wells in the north and north central Sinai have been characterized by means of a variety of organic geochemical techniques (C 7 hydrocarbon and biomarker analyses), to illustrate origin, differences, and similarity among oils. These oils were obtained from Cretaceous and Jurassic reservoirs. The C 7 oil correlation star diagram (OCSD) suggests closely related oils, derived mainly from similar source rocks, while the C 7 oil transformation star diagram (OTSD) and C 7 light hydrocarbon analyses indicate a minor degree of transformation of some oils, as Misri-1, Halal-1, and Nakhl-1 oils were subjected to evaporative fractionation. Moreover, the studied oils show no sign of water washing and biodegradation. Molecular characteristics suggest pre-Tertiary shales and carbonate source rocks, deposited under a saline oxic environment, rich in terrigeneous organic sources with significant bacterial and algal input. Since the studied oils are of mixed marine and terrestrial origin, C 7 signature of these oils is not representative of their origin and should be supported by other geochemical evidence (e.g., biomarkers) to predict their origin. [ABSTRACT FROM AUTHOR]

Sixteen cutting and four core samples, in addition two crude oil samples are representative for the Miocene source rocks and reservoirs in some wells in the southern part of Gulf of Suez. These samples were subjected to advanced geochemical tools (pyrolysis, elemental analyses, gas chromatography, and gas chromatography-mass spectrometry). In addition, burial history model of the deepest well is recognized. The results showed that the Middle-Upper Miocene source rocks are immature, originated mainly from mixed organic sources, have poor to fair potentiality to produce oil, and did not reach the early stage of hydrocarbon generation until the present time. Lower Miocene source rocks are mature, derived from marine organic sources, have good potential to generate oil and gas, and entered the early stage of hydrocarbon generation and oil window till present time. The crude oil samples are mature, originated mainly from marine sources, and show good correlation with the Lower Miocene source rocks. Therefore, the Lower Miocene source rocks may be considered an effective source for oil generation in the southern part of Gulf of Suez. [ABSTRACT FROM AUTHOR]

The Pan-African basement exposed in the Meatiq area, Central Eastern Desert, Egypt, was found to possess tectonic styles belonging to infrastructure, transition and super-structure levels. Tectonic style of the infrastructure was developed during an old orogeny in the Lower Pan-African, and overprinted by those of the transition and superstructure levels of a younger orogeny in the Middle and Upper Pan-African, respectively. In the Lower Pan-African, old sequences of sediments and volcanics, together with ophiolitic rocks, were intensely deformed and regionally highly metamorphosed into gneisses and amphibolites. In the infrastructure level such rocks were migmatized, plastically deformed and intruded by synkinematic granitoid (diorite to alkali granite) lenses, sheets and plutons which were probably crystallized as amphibolite-facies gneisses. Later on, these infrastructural rocks were cut by mafic to intermediate dykes and sills, isostically uplifted and cratonized. Parts were exposed to erosion. In the Middle Pan-African the cratonized rocks sank into a transition tectonic level where they underwent large-scale thrusting, varying degrees of cataclasis and mylonitization, and low- to medium-grade regional metamorphism. An episode of plutonism guided by thrusts followed, mainly in the form of synkinematic intrusion of tonalite, granodiorite and quartz monzodiorite. In the Upper Pan-African, isostatic uplift occurred and the mylonitic rocks attained the superstructure level. There they were subjected to two main phases of folding resulting in the major Meatiq domal structure. Subsequently, the folded rocks were intruded by a postkinematic quartz monzonite pluton. [ABSTRACT FROM AUTHOR]

[Display omitted] • The shales of the Kom Ombo Formation are organic-rich sediments, with TOC value of up to 6.61 wt%. • The organic facies are predominantly of Types II and II/III kerogen. • Kom Ombo shales were deposited in a marine under anoxic environmental conditions. • The shales reached peak oil-window and generated commercial amounts of oil. This study uses organic geochemical and petrographic analyses to characterise the organic-rich shales from the Lower Cretaceous Kom Ombo Formation in the Kom Ombo Basin. The overall results show that the Kom Ombo shales are considered to have good petroleum source rock potential with total organic carbon (TOC) content > 1 wt% and hydrocarbon yields of up to 27.62 mg hydrocarbons/g rock. Based on lipid biomarker ratios and carbon isotopes, the Kom Ombo shale contains a blend of organic matter derived primarily from algal marine and other aquatic organic matter, with some terrigenous land plants, deposited under anoxic conditions. These findings of organic matter (OM) input and depositional conditions are consistent with the high TOC content of up to 6.61 wt% and mainly Types II and II/III kerogen, with small amounts of Type III kerogen, thus yielding both oil and gas, with oils of high to low wax contents. Geochemically, the dominance of oil generation potential is in agreement with the presence of considerable concentration of fluorescent liptinite macerals. The chemical and optical maturity results show that the majority of the examined Kom Ombo shale samples have entered the main stage of oil generation, exhibiting a range of early-mature to late-mature. Therefore, as highlighted in this study, the oil generation potential of the Kom Ombo shales may represent a good opportunity for future conventional petroleum exploration. [ABSTRACT FROM AUTHOR]

Rock-Eval pyrolysis/TOC, petrographic, and geochemical data available in the public domain for a total of 296 core and 243 drill cuttings samples from the Albian-early Cenomanian Kharita and Bahariya formations of four main basins, Shushan, Abu Gharadig, Matruh and Dahab-Mireir, were reviewed. This review provides a comprehensive overview to understand the organic richness, type, and thermal maturity of potential source rock intervals within the Kharita and Bahariya formations in northern Egypt by means of burial history modeling and oil-in-place calculations. Geochemical data of both formations confirmed the presence of up to excellent source rocks of varied kerogen types but mainly of Type III (gas-prone) and mixed types II/III. Thermal maturity levels ranged from immature to the early stage of oil window, although some intervals reached the peak oil window in the Abu Gharadig and Shushan basins compared to their counterparts. The depositional paleoenvironment of the Kharita and Bahariya formations is interpreted based on the organic biomarker compounds and palynofacies associations. Generally, both formations in the four basins were interpreted to accumulate in a fluvio-deltaic to marginal marine setting, although the Kharita rock unit was slightly less marine based on the isoprenoids pristane and phytane to nC 17 and nC 18 ratios. The ratio of 22S/(22S + 22R) for the homohopanes C 31 and C 32 of Kharita oils from the Shushan Basin ranged from 0.50 to 0.60, indicating marginally mature to the onset of oil generation. However, common amongst much of the previous studies was the notable differences in organic matter contents, thermal maturity levels and hydrocarbon potential. Environmental and ecological processes, including proximity to shoreline, terrestrial/riverine input, oxygenation levels and water column conditions, are considered the primary drivers that triggered variable amounts of organic carbon accumulation. While differences in thermal maturity levels were attributed to tectonic activities and related structural processes. • Fair to good organic matter-richness in the Bahariya and up to excellent for the Kharita Formation was reported. • The source rock beds within the both formations have variable kerogen types (Type III, II/III and II). • Levels of maturation in both formations were mainly immature to early mature with minor intervals in peak stage of oil window. • The Kharita and Bahariya formations had the highest yield of oil‐in‐place in the Matruh Basin. • Despite the Kharita was less marine than Bahariya, both formations were deposited in fluvio-deltaic/marginal marine settings. [ABSTRACT FROM AUTHOR]

Abstract The Mukalla Formation is one of the important petroleum source rocks in the Jiza-Qamar Basin, Eastern Yemen. In this study, coal, coaly shale and shale samples from three wells (Al-Fatak-1, 16/G-1 and 16/E-1) in the offshore Jiza-Qamar Basin were studied. The organic matter richness, kerogen type, thermal maturity, and petroleum generation potential of the Mukalla organic-rich samples were investigated. The analysed Mukalla source rock samples are potentially rich in organic matter of 1.01–84.40% TOC, ranging from good to excellent source rocks. The Mukalla source rocks primarily contain Types II, II–III and III kerogen, anticipating generating mainly oil and gas. This is generally consistent with the pyrolysis–gas chromatography results and further indicates that the Mukalla source rocks can produce high wax oil and condensate/gas. The thermal maturity parameters reveal the Mukalla source rocks are in mature to late-mature and are capable of generating oil and wet gas at the present time. In addition, this study was integrated the geochemical, geo-thermal and geological data in term of basin modeling study to simulate the timing of hydrocarbon generation and expulsion from the Mukalla deltaic source rocks. The basin model results indicate that the oil generation commenced during the late Eocene to late Oligocene, with a conversion ratio of 10–50 TR%. Furthermore, based on TRs of more than 50%, the most of oil was expelled along the micro-fracturing of the Mukalla source rocks and then trapped in the Mukalla Formation itself during the latest Oligocene and continued to present-day. Highlights • The Mukalla Formation in the offshore Jiza-Qamar Basin is considered as a deltaic source rock. • Basin models were constructed from three wells in the offshore Jiza-Qamar Basin. • Mukalla source rocks reached the late oil-window in the present-day. • The oil was generated during late Eocene to late Oligocene, with a conversion ratio of 10–50%. • The oil was then expelled along the micro-fracturing of the Mukalla source rocks. [ABSTRACT FROM AUTHOR]

A comprehensive set of organic and inorganic geochemical proxies, clay mineralogy, and molecular fossils are presented from two biostratigraphically well-dated oil shale horizons of Egypt, within the Upper Cretaceous Duwi and Dakhla formations. The studied oil shales were deposited within intracratonic sedimentary basins in a broad northern African epeiric sea. Calcareous nannofossil biostratigraphy indicates that the oil shales range from early to late Maastrichtian in age, covering nannofossil zones UC18, UC19, and UC20. The oil shales contain smectite and kaolinite as the main clay minerals that formed by weathering of precursor basement rocks. The relative abundances of clay minerals and several geochemical proxies (e.g. C-value, CIA, Ga/Rb, Rb/Sr and Sr/Cu), along with the occurrence of warm-water nannofossil taxa, demonstrate that the Maastrichtian oil shales accumulated under a warm, arid to humid greenhouse climate during a general Maastrichtian cooling trend. This episode of oil shale deposition in Egypt coincided with the first potential imprint of the global warming, that has been recorded during early-to-late Maastrichtian times (~70.6–67.7 Ma). Elevated eolian terrigenous input was recorded within the Duwi Formation oil shales, shown by high Ti/Al, Si/Al, Zr/Al and low La/Lu ratios. The Duwi Formation environment was characterized by enhanced salinity and a stratified water column, compared to that of the Dakhla Formation, shown by elevated values of the gammacerane index, tetracyclic terpane, β‑carotene and Sr/Ba ratio. The CaCO 3 content and carbonate/siliciclastic ratio indicate that the Dakhla Formation oil shales were deposited during a relative sea-level rise in a deeper marine setting than the Duwi Formation oil shales. The data further imply a wind-driven upwelling scenario of nutrient input s that simulated primary production and increased organic matter fluxes. Thus, paleoclimate and paleoceanography had a considerable impact on organic matter enrichment. [ABSTRACT FROM AUTHOR]