Mohamed M. El Nady

Egyptian Petroleum Research Institute | EPRI · Department of Exploration

The biochemistry of biomarkers, known as biomarkers, is a group of compounds, especially hydrocarbons in oils, rock extracts, sediment extracts, and soil extracts. The most important characteristic of other compounds in oil is that biomarkers can be called "molecular fossils" reasonably. Vital indicators are structurally similar to specific natural products (compounds produced by living organisms). Usually, biomarkers retain all or most of the original carbon structure of the original natural product, and this structural similarity is what leads to the term "molecular fossils".

البترول سائل يتكون أساسآ من الهيدروكربونات وكذلك نسبة صغيرة من الكبريت والاوكسجين والنتروجين، تتكون وتتجمع في باطن الارض وتظل في مكانه الى ان يخرج الى سطح الارض بفعل العوامل الطبيعية كالشقوق- الفوالق أو الكسور الارضية أو يستخرجها الانسان بحفر الآبار. يوجد البترول في الطبيعة إما في حالة صلبة أو شبه صلبة كعروق الاسفلت، أو يوجد في حالة سائلة كخام البترول أو في حالة غازية. ويتنوع إنتاج حقول البترول، منها ما ينتج خام البترول مختلطآ بقليل من الغازات الطبيعية، ومنها ما ينتج أساسآ من الغازات الطبيعية مع قليل من خام البترول أو بدونه كحقول الغازات الطبيعية.

البيولوجيكالماركرز اوالبيوماركرز والتى تعرف بالمؤشرات اوالدلائل الحيوية هي مجموعة من المركبات خاصة الهيدروكربونات الموجودة في الزيوت ومستخلصات الصخور ومستخلصات الرواسب الحديثة ومستخلصات التربة. اهم ما يميزها من المركبات الأخرى في الزيت هو أنه يمكن أن يطلق على المؤشرات الحيوية "الأحافير الجزيئية" بشكل معقول. تعتبر المؤشرات الحيوية مشابهة من الناحية الهيكلية لمنتجات طبيعية محددة (وهي مركبات تنتجها الكائنات الحية). عادة تحتفظ المؤشرات الحيوية بكل أو معظم هيكل الكربون الأصلي للمنتج الطبيعي الأصلي ، وهذا التشابه البنائى هو ما يؤدي إلى مصطلح "أحافير جزيئية".

الكروماتوجرافيا طريقة لفصل المكونات أو المواد المذابة في محلولٍ أو وسطٍ ما، وتعتمد في الأساس على سرعة المكونات المختلفة وفقًا لبعض الخصائص التي تمتلكها بعض المركبات. يوجد في هذا الأسلوب من الفصل مكونان أساسيان هما الوسط المتحرك (mobile phase) والوسط الثابت .(stationary phase) يمكن للوسط المتحرك أن يكون سائلًا أو غازًا، والوسط الثابت يمكن أن يكون صلبًا أو سائلًا حيث يختلفان تبعًا لطريقة الفصل وطبيعة المواد المراد فصلها

This study describes the fingerprinting of crude oils from different Egyptian oil formations using gas chromatography (GC) and gas chromatography mass spectrometry (GC–MS). The samples were obtained from Gindi, Abu El gharadig, south deep Abu El gharadig, Dahab- Merier and Faghur basins from Western Desert. Diagnostic biomarkers parameters applied in this study provide evidences about the source of organic matter, the depositional environment and maturity of the studied oils. The results showed that the crude oils of Faghur basin are believed to be originated from mixed source predominately terrestrial with chief contribution of clastic rocks deposited under oxic conditions. However, the crude oils from Gindi, Abu El gharadig, South deep Abu El gharadig and Dahab- Merier basins were generated from marine carbonate source rock deposited under anoxic depositional environment.

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.

Certificates Of Journal of African Earth Science

يمكن للأمراض الجديدة أن تقدم للمجتمع الطبي العديد من المشاكل، وكذلك الفروع الجديدة في عِلم الطب قد تقدم للمجتمع الطبي فرص جديدة لمعالجة مجموعة من المشاكل الصحية بما في ذلك الأمراض الجديدة. ومن اهم هذه الفروع الجديدة هي «الجيولوجيا الطبية»، فرع سريع النمو ولديه القدرة على مساعدة المجتمعات الطبية لمعالجة مجموعة واسعة من قضايا الصحة البيئية .يمكن اعتبار الجيولوجيا الطبية متمِّمَة للصحة البيئية للتعامل مع آثار المواد والعمليات الجيولوجية على صحة الإنسان والحيوان. تجمع الجيولوجيا الطبية علماء الجيولوجيا والباحثين في مجال الصحة العامة لمعالجة المشاكل الصحية الناجمة عن أو المتفاقمة بسبب المواد الجيولوجية مثل العناصر الشحيحة والصخور والمعادن والغبار، والمياه، والعمليات الجيولوجية مثل الانفجارات البركانية والزلازل. ولاتعتبر الجيولوجيا الطبية فرع ناشئ أومستحدث؛ فقد عُرِفَت العلاقة بين المواد الجيولوجية مثل الصخور والمعادن وصحة الإنسان لعدة قرون. تصف النصوص الصينية القديمة والمصرية والإسلامية واليونانية العديد من التطبيقات العلاجية لمختلف الصخور والمعادن والعديد من المشاكل الصحيَّة التي قد تسببها. قبل أكثر من 2000 عام، حيث وصفت النصوص الصينية 46 معدن مختلف كانوا يستخدموا للأغراض الطبية، ولقد ظهرت معادن الزرنيخ على سبيل المثال على نطاق واسع في المواد الطبية من الثقافات القديمة. قبل اكتشاف البترول والتنقيب عنه وحفر الآبار كان البترول بيطلع على السطح فى صورة طفح او نشع زيتى ان لم يجد مصيدة تحت السطح لحجزه فبتتبخر وتطاير كل الزيوت الخفيفة ولَم يتبقى سوى البيتومين على شكل برك زيتية اللى كانت بتستخدم فى علاج الأمراض الجلديه والادوية واستخدمها المصريين القدماء فى التحنيط.

The objectives of this study are the correlation between the oil samples recovered from the Lower Cretaceous reservoirs and Lower and Upper Cretaceous source rocks. The investigated biomarkers of five oils indicated the oils were derived from mixed marine and terrigenous (lacustrine) organic matter and deposited under suboxic to anoxic conditions. These oils were also generated from source rocks of high thermal maturity at the peak oil window. So, based on the molecular indicators of organic source input ,depositional environment and maturity parameters of oils and extracts, we can conclude that the oil recovered from Al Baraka oil field were derived from Lower Cretaceous source rocks especially KomOmbo (B) source rocks where it reached the oil window. Furthermore, we can indicate that the other lower Cretaceous formations as Abu Ballas Formation will have the opportunity to generate and expel oil at the deeper part of the basin as shown in the eastern part of the basin.

The pyrolysis and vitrinite reflectance estimations for fifteen shale rock tests and additionally, geochemical burial history, and gas chromatography – mass spectrometry parameters were talked about to explore the hydrocarbon generation and maturation level and time, type of hydrocarbon produced of rock units of Safir-1xwell. The results assign that the Bahariya Formation is poor to great source rock to create oil and gas, with a lower thermal maturation degree than the Khatatba and Alam El Bueib formation. Alam El Bueib is viewed as good to excellent source rock for oil and gas age, having marginally high level of thermal maturation at oil window at around 40 million years. Khatatba formation achieved the oil and gas generation window at about 80 and 50 million years separately and considered excellent source rock. The molecular gas chromatography and mass spectrometry parameters demonstrated that the extracts of source rocks reflected that the Bahariya and Alam El Bueib extracts have a mixed sources formed under transitional conditions at low grad of thermal maturation. Khatatba source rock extracts originated from marine sources formed under reducing conditions at high grade of maturation.

Effect of provenance of organic matter evaluated through the distribution of occurrence of triterpanes and steranes in surface sediments from coastal stations located in the Gulf of Suez Gulf. The samples have been studied in four coastal stations located in the Gulf of Suez namely: Al–NasrOil Company (NPC), West outlet of SOPC, Inlete of SOPC, and El-Sukhna of Loloha Beach. Saturated hydrocarbons were analyzed by gas chromatography–mass spectrometry, to assessing of organic content and maturity level of the sediments. The results showed that the hydrocarbons are originated mainly from predominance of petrogenic and biogenic hydrocarbons with high maturity level.

This paper aims to evaluate the hydrocarbon potentiality and thermal maturity of the Cretaceous source rocks in Al Baraka oil field in KomOmbo basin, south Egypt. To achieve this aim, geochemical analyses (TOC), Rock eval pyrolysis and vitrinite reflectance measurements (R0) were carried out on the studied rocks. The analytical results of the samples that were collected from five exploratory oil wells revealed that almost Lower Cretaceous formations (Sabaya, Abu Ballas, Six Hills and KomOmbo C, B, A) and Upper Cretaceous formations (Dakhla, Duwi, Quseir, Taref and Maghrabi) are ranged from fair to excellent source rocks for hydrocarbon generation. Oil and gas are mainly the future products of the thermally transformed organic matters within almost samples of the Cretaceous formations, where the Lower and Upper Cretaceous formations contain mixed type II/III and III kerogen besides type II kerogen in KomOmbo (B) and Dakhla formations. The thermal maturity parameters clarified that the Lower Cretaceous formations are belonged to marginally mature (in Sabaya and Abu Ballas formations), whereas the rocks of KomOmbo (B) Formation are mature source rocks and fall in the stage of oil generation and reach to the late stage of oil generation (R0 = 1.25). On the contrary the Upper Cretaceous formations are ranged from immature to marginally mature source rocks and reach only the early stage of oil generation in Maghrabi Formation. This study indicated that there is still a good chance to find oil generated from the Dakhla, Duwi, Maghrabi, Sabaya and Abu Ballas formations if buried in greater depths as well as, KomOmbo B and A intervals which are source rock potentials.

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 CaCO3 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 inputs that simulated primary production and increased organic matter fluxes. Thus, paleoclimate and paleoceanography had a considerable impact on organic matter enrichment.

This paper aims to evaluate the hydrocarbon potentiality and thermal maturity of the Cretaceous source rocks in Al Baraka oil field in KomOmbo basin, south Egypt. To achieve this aim, geochemical analyses (TOC), Rock eval pyrolysis and vitrinite reflectance measurements (R0) were carried out on the studied rocks. The analytical results of the samples that were collected from five exploratory oil wells revealed that almost Lower Cretaceous formations (Sabaya, Abu Ballas, Six Hills and KomOmbo C, B, A) and Upper Cretaceous formations (Dakhla, Duwi, Quseir, Taref and Maghrabi) are ranged from fair to excellent source rocks for hydrocarbon generation. Oil and gas are mainly the future products of the thermally transformed organic matters within almost samples of the Cretaceous formations, where the Lower and Upper Cretaceous formations contain mixed type II/III and III kerogen besides type II kerogen in KomOmbo (B) and Dakhla formations. The thermal maturity parameters clarified that the Lower Cretaceous formations are belonged to marginally mature (in Sabaya and Abu Ballas formations), whereas the rocks of KomOmbo (B) Formation are mature source rocks and fall in the stage of oil generation and reach to the late stage of oil generation (R0 = 1.25). On the contrary the Upper Cretaceous formations are ranged from immature to marginally mature source rocks and reach only the early stage of oil generation in Maghrabi Formation. This study indicated that there is still a good chance to find oil generated from the Dakhla, Duwi, Maghrabi, Sabaya and Abu Ballas formations if buried in greater depths as well as, KomOmbo B and A intervals which are source rock potentials.

East Beni Suef Concession is located in the eastern part of Beni Suef Basin which is a relatively under-exploration basin and lies about 150 km south of Cairo city. Rock-Eval pyrolysis and well logs data from three wells (Gharibon-1x well, Gharibon NE-1X and Tareef-1X well) in the Gharibon oil field, East Beni Suef basin were used to evaluate the organic matter richness, generation, maturation and kerogen type of the Cretaceous source rocks. This study represents the first attempt to investigate the petroleum geochemistry of the Cretaceous sequences in Gharibon oil field. The assessment of the source rock has been done by using different methods such as well logging data, Rock-Eval pyrolysis and Vitrinite reflectance (%Ro) of some Cretaceous sequences comprise Apollonia, Khoman, Abu Roash (A, E, F and G members), and Baharyia formations. The geochemical analysis includes pyrolysis data which are total organic carbon (TOC %), generating source potential (S2), oxygen and hydrogen indices (OI, HI), production index (PI) and (Tmax). On the basis of TOC and Rock-Eval pyrolysis results, three main source rock types could be distinguished in the studied wells. The first source rock type is oil-prone, while the second source rock type is mixed oil/gas-prone and the third source rock type is mainly gas - prone.

بعد الثورة الصناعية التي شهدها العالم في القرون الأخيرة، برزت الحاجة لوجود مصادر الطاقة التي تزود آلات المصانع ووسائل النقل بالطاقة التي تمكنها من القيام بعملها، فتم اكتشاف الوقود الأحفوري والنفط والغاز الطبيعي. مع تنامي خطر نضوب مصادر هذه الطاقة والصراعات على هذه المصادر التي خلفت الدمار في العالم، جاءت ضرورة البحث عن مصادر متنوعة للطاقة التي تستطيع من خلالها هذه الدول توليد الطاقة الكهربائية لتشغيل الآلات والمصانع وتزويد المشروعات التنموية العملاقة بالطاقة اللازمة لاستدامتها. من هذه المصادر الطاقة الشمسية التي لاقت رواجاً كبيراً في العالم حيث أنها طاقة متوافرة طبيعياً من الشمس كما أنها طاقة صديقة للبيئة لا تشكل خطراً عليها، ومنها أيضاً طاقة الرياح وطاقة المياه وما يعرف بالطاقة النووية. الطاقة النووية هي الطاقة التي تنتج عن طريق التفاعلات النووية الذرية، وهي الطاقة المستخدمة في توليد الطاقة الكهربائية الضرورية لجميع مناحي الحياة في تشغيل الآلات والأجهزة الكهربائية ووسائل أو أجهزة الاتصالات وغيرها، والناتجة عن طريق تبخير المياه لإنتاج الطاقة الكهربائية. تعتمد الطاقة النووية على اليورانيوم، والذي يتم استخراجه من الأرض عن طريق تعدينه، فتنشطر ذرات هذا العنصر عن طريق الانشطار النووي، والتي يتم التحكم فيها بدقة متناهية جداً، فأي خلل فيها ينجم عنه كوارث هائلة لا تحمد عاقبتها، إن عملية الانشطار البطئ تتم في المفاعلات النووية المستخدمة في التوليد الطاقة، أما الانشطار السريع فيتم عند تفعيل واستخدام الأسلحة النووية الفتاكة. لاقت الطاقة النووية انتشاراً واسعاً في العالم، على الرغم من تكلفة إقامتها الكبيرة، وعلى الرغم أيضاً من آثارها البيئية - في حالة حدوث تسرب إشعاعي - على البيئة المحيطة بالمنشأة النووية، لذلك فالمحاولات قائمة في بعض الدول الغربية على إحلال الطاقة النظيفة كالطاقة الشمسية بدلاً من الطاقة النووية أو النفط أو الوقود أو الغاز الطبيعي. ورغم ذلك فهناك العديد من الدول تشجع إقامة مفاعلات الطاقة النووية للحصول علي احتياجاتها من الطاقة المستدامة ومنها الصين والهند وباكستان وجنوب إفريقيا ومصر والإمارات الغربية والسعودية وغيرها. إنتاج الطّاقة من المفاعلات النووية يتم نتيجة عمليات التحكم في تفاعلات في الوقود النووي داخل قلب المفاعل، ينتج عنه توجيه نيوترات نحو نوى ذرات اليورانيوم مما يؤدي إلى انشطارها مكونه نيوترات أخرى تهاجم نواة ذرات أخرى مسببةً سلسلة من الانشطارات النووية، وفي كل حالة انشطار تطلق طاقة حراريه هائلة تعمل علي تسخين المياه الموجودة حول لب المفاعل والتي بدورها تتحول إلي أبخرة ماء بدرجة حرارة عالية وتحت ضغط كبير، ومن ثم تعمل على تحريك زعانف التوربينات و توليد الطّاقة الكهربائية التي ينتفع منها الناس.

Eight crude oils collected from different oilfields distributed within the northern, central and southern Gulf of Suez basin to detect the distribution of triterpanes and steranes biomarkers as indication of organic matter input and depositional environments of crude oils and lithology of organic matters. This achieved throughout the application of gas chromatography mass spectrometry analysis. The results revealed that the Gulf of Suez samples are believed to be of marine organic matter input deposited under anoxic depositional environment. Off shore samples S3 and S4 from Central Province of Gulf of Suez basin show low maturity levels, while the other samples which were of higher maturity levels.

Asian Journal of Geological Research 2018

The compositions of polycyclic aromatic hydrocarbons used as chemical markers for the identifying of different sources in the surface seawater of Alexandria coastal area. The quantitative analysis of polycyclic aromatic hydrocarbons (PAHs) showed a concentration ranged from 8970.939-1254756.00 ng/L, which exceed the maximum admissible concentrations of PAHs (200 ng/L) for the water standard of European Union. The calculated diagnostic ratios suggested that the sources of PAHs at the majority of the studied area are derived primarily from pyrogenic sources from incomplete fuel combustion of the boats and vehicle engines with lesser amounts of PAHs contributed from petrogenic sources. Some stations displayed mixed sources in comparison to many other studied marine systems, the PAHs concentrations detected at Alexandria area were considered be higher to pose health risks to aquatic bodies.

Characterization and correlation of crude oils from some wells in the North Western Desert, based on six crude oil samples, were studied by different analytical techniques, including API gravity, sulfur content, nickel and vanadium, bulk compositions and saturated fraction obtained from gas chromatography have been studied. The results show that the crude oils are normal to medium aromatic oils, with high API gravity and high sulfur content. V, Ni, V/Ni and V/(V + Ni) reflecting oils might be sourced from non-clastic source rocks, possibly carbonates, deposited under anoxic-suboxic conditions. Bulk compositions revealing that the crude oils were derived from marine organic sources. While, the paraffins and naphthenes percent indicates that the oils belong to paraffinic to naphthenic oil types, deposited in slightly anoxic to suboxic conditions and contained marine organic matter. Thermal maturity data showed that the oil samples were generated from mature source rocks. This indicates the studied oil samples are well correlated with each other, where they are similar in their oil type maturation and source depositional environments.

In the present study, the geochemical analyses of API gravities, vanadium, nickel, sulfur, and bulk composition were performed on eight samples from productive wells in Gindi, South Deep Abu-Ghradig, Abu-Gharadig, Dahab Merier, and Faghure basins locates in the North Western Desert. The results were used to describe the source organic matter input, depositional environment, assess the degree of thermal maturity, and to correlate between crude oils to determine the genetic relationship between hydrocarbon generation and their source rock for the studied oil samples. The results showed that a wide range of crude oil parameters exists in this data, indicating that a variety of oil types is represented. Crude oils range from unaltered to altered by vanadium, nickel, and sulfur concentrations, V/Ni and saturate fraction were used to classify the oils. Oils are classified into two groups. Group I contains oil samples from Gindi, South deep Abu-ghradig and Abu-Gharadig, and Dahab Merier that are generated from organicmatter input deposited in marine environment under anoxic Q1 to relatively suboxic conditions. Group II from Faghur basin possess high Pr/Ph ratios suggesting high contribution of terreginous organic matter deposited under relatively oxic conditions.

الجيوكيمياء هو علم حديث، ظهر في مطلع القرن العشرين، وينتمي إلى مجموعة علوم الأرض التي تدرس تركيب الكرة الأرضية وبنيتها وتاريخها الجيولوجي. وقد نشأت الجيوكيمياء نتيجة تراكم أعداد كبيرة من الدراسات الجيولوجية والكيميائية، وللحاجة الماسة لحل كثير من المسائل المرتبطة بأعمال التنقيب عن مكامن الخامات المفيدة.

The Semi-enclosed Suez Gulf records various signals of high anthropic pressures from surrounding regions and the industrialized Suez countries. The sedimentary hydrocarbons have been studied in 6 coastal stations located in the Gulf of Suez. Non-aromatic hydrocarbons were analyzed by GC/FID and GC/MS to assess organic content in surface sediments of Suez Gulf, Egypt depending on alkanes, terpanes and steranes biological markers indicators. The results showed that the hydrocarbons are originated from multiple terrestrial inputs, biogenic, pyrolytic. Several ratios of hydrocarbons indicated the predominance of petrogenic in combination with biogenic hydrocarbons. Al-Attaqa harbor, Suez oil processing company, Al-Nasr Oil Company, AL-Kabanon and EL-Sukhna of Loloha Beach are the main sources of petroleum contamination.

This paper represents the first comprehensive survey and provides important data on PAHs concentration and composition in Alexandria coastal seawater. The compositions of PAHs determined in all samples are to be used as chemical markers for identifying different sources of PAH pollution in the surface seawater of Alexandria coastal area. The quantitative analysis of PAHs showed a concentration ranging from 8970.939 to 1254756.00 ng/L, which exceeds the maximum admissible concentrations of PAHs (200 ng/L) for the water standard of European Union. The calculated diagnostic ratios suggested that the sources of PAHs at the majority of the studied area are derived primarily from pyrogenic sources from incomplete fuel combustion of the boats and vehicle engines with lesser amounts of PAHs contributed from petrogenic sources. Some stations displayed mixed sources in comparison to many other studied marine systems, the PAH concentrations detected at Alexandria area were considered to be higher and pose health risks to aquatic bodies.

The Late Jurassic-Early Cretaceous Chia Gara Formation is an important oil-source rock in Iraqi Kurdistan region. Chia Gara source rock is characterised by high organic matter and sulphur content with Type II_S kerogen. 1D basin models were integrated with geological information and geochemical data from Chia Gara Fm at four well locations in Kurdistan region, northern Iraq. The models of the burial/thermal history indicate that Chia Gara Fm is presently in the peak-oil generation window and some oil cracked to gas during Late Eocene to Late Miocene time. Onset of oil-generation began during the Middle Paleocene- Early Oligocene (60-30 Ma). Oil was generated during the Late Eocene to Late Miocene (48-9 Ma). The models also suggest that the oil was expelled from Chia Gara source rock during the Late Eocene to Late Miocene (37-9 Ma), with a transformation ratio more than 50%. The high transformation ratio of more than 80% in two wells suggests that the generated oil was cracked to gas during the end of Middle Miocene time and continued to present day. The basin modeling results further suggest that Chia Gara Formation acts as a prolific petroleum-source rock and significant of oil and limited of gas have been generated and expelled to any nearby prospect reservoir rocks in the Kurdistan region.

Certificate of International Journal of Biochemistry Research and Review 2017

Certificates Microbiology Research Journal International 2017

Two gasoline samples were collected from Saudi Arabia petrol station and subjected for studying their quality as liquid fuel. Gasoline samples were characterized and compared by studying their physicochemical properties such as average molecular weight, relative density, percent carbon, percent hydrogen, total oxygen content, and octane number. In addition, it was performed to study the group analysis and detailed hydrocarbon composition of automotive gasoline samples via gas chromatographic (GC) fingerprints as a practical method for quality detection.

Eight crude oil samples from the Gulf of Suez oil fields were analyzed by using GC-MS. Biomarker characteristics are used to provide information on source organic matter input, depositional environment and maturation level. Data includes normal alkanes and a cyclic isoprenoids distribution, tarpanes and steranes aliphatic biomarkers. The biomarkers are characterized by a dominance of low to medium molecular weight n-alkane compounds with significant waxy n-alkane (nC25-nC35), low pr/ph ratio (<1.0), high proportions of hopanes relative to tricyclic terpanes, Ts/Tm ratio of the oil samples ranged from (0.25 to 1.00) this together with the high sulphur contents, high values of C35/C34 and high C27 regular steranes. The biomarker parameters reflecting that the oils were derived from carbonate source rocks contain aquatic (algal and bacterial) organic matter with minor terrigenous organic matter contribution that were deposited in marine environments under reducing conditions and generated at different maturities.

Biography of Mohamed El Nady ( English )

Marquis Who's Who is the American publisher of a number of directories containing short biographies.

Albert Nelson Award 2017

The aim of this study was to investigate the contamination of surface sediments in Suez Gulf, Egypt, by polycyclic aromatic hydrocarbons (PAHs). Total concentrations of 16 PAHs were ranged from 6.6009 to 1770.3265 ng/g sed. dry wet with an average of 398.617 ng/g sed. dry wet, which is relatively high in comparison with other estuaries around the world. Source identification implied that the PAHs were originated mainly from pyrolytic sources. However, source patterns may be continuously changed to a petrogenic origin due to the heavy ship traffic and continuous discharge of oily sewage in this area. The PAH levels were also compared with international Sediments Quality Guidelines and Sediments Quality Criteria, and the results indicated adverse effects for most individual PAHs. However, toxic effects related to acenaphthylene (A); benzo [b] fluor-anthene (Bbf); benzo [K] fluoranthene (Bkf); dibenzo [a,h] anthracene (DahA); and benzo [ghi] perylene (Bp) would occur occasionally in most locations in the Gulf.

The objectives of this paper are providing a level of contamination of superficial coastal sediments by hydrocarbons from the coastal zone of the Suez Gulf through the evaluation of aliphatic and alicyclic hydrocarbons analyses using capillary column and gas chromatography. The locations were selected to cover about 18.7 km from the Suez Gulf coast taking into consideration the expected polluted area due to industrial and human activities. The results showed that the three levels of Suez Gulf was classified as highly polluted concentration in sediments and was categorized into four levels (guideline μg/g): unpolluted area/natural background level (10–15), slightly polluted area/upper permissible limits (15–50), and moderately polluted area (50–200). Therefore, the anthropogenic hydrocarbon inputs were more apparent at sites associated with industrial discharges (petroleumdistributor and refinery), shipping activities (dry docking), and sewage outfalls (sewage); in addition, the chronic oil pollution in the area may be due to the large quantities of refined products and the limited capabilities of water treatment units located in the study area.

The organic matters of Rudeis and Kareem formation from Ras Budran oilfield in the central Gulf of Suez, Egypt, were investigated throughout the study of biomarkers analyses. The results showed that Pr/Ph, Pr/n-C17, and Ph/n-C18 ratios indicated marine source organic matters deposited under reduced condition with a less effect of biodegradation and mature stage of occurrence. The gammacerane index indicated a low-salinity environment of deposition for the initial organic matters existed in the analyzed samples. Steranes distributions show high percentage of C28 steranes and C29 steranes compared with C27 steranes, and low-concentration C27 diasteranes show generally low ratios indicating anoxic carbonate source rocks. The diasteranes/steranes showed generally low ratios indicating most marine carbonate sources. The tricyclic terpane reflects mature organic matters and originated from marine organic sources.

The TOC-Rock-Eval pyrolysis and vitrinite reflectance measurements for “15” shale rock samples, as well as, multivariate statistical analysis are discussed to investigate hydrocarbon, source rock characteristics, correlation between the assessed parameters (S1, S2, HI, S1+S2, QI, BI, PI, TOC) and the impact of changes in the Tmax and Ro% on the assessed parameters in Safir exploratory-1x well in Safir oil field. The geochemical analysis indicated that the Bahariya Formation is considered to be a poor source rock for oil generation with a low degree of thermal maturation in comparison with the Alam El Bueib and Khatatba formations. However, Alam El Bueib is found to be a good source rock for oil generation with slightly higher thermal maturation. Interestingly, Khatatba Formation lies within the oil and gas generation window and show an excellent source rock potential. Based on statistical findings of cluster and factor analysis, the source rocks in the study area are classified into two types corresponding to two different clusters. Cluster I includes Alam El Bueib and characterized by kerogen type II and II/III whereas, cluster II, characterized by kerogen type III, is subdivided into two subgroups (IIa and IIb) and represents Bahariya and Khatattba source rocks. Nonparametric tests (K-independent samples) between the dataset of 15 samples confirm that the distribution of values from respective parameters exhibits significant difference (P<0.05) except for PI and BI. On the other hand, the nonparametric tests (2-independent samples) showed that there is no significant difference (P>0.05) in the distribution of HI and QI values indicating that both HI and QI values remain constant with increasing thermal maturity. Unlike TOC and HI, Pearson’s and linear regression analysis indicated a significant correlation between TOC and S2. Nevertheless, two different trends were observed between S1 and S2. Moreover, the Ro% and Tmax were found to be positively correlated. Interestingly, our study showed that no significant correlation between HI, QI, BI and thermal maturity (Ro% and Tmax), while, a good correlation between TOC, S2 and thermal maturity was observed.

The organic matters of Rudeis and Kareem formation from Ras Budran oilfield in the central Gulf of Suez, Egypt, were investigated throughout the study of biomarkers analyses. The results showed that Pr/Ph, Pr/n-C17, and Ph/n-C18 ratios indicated marine source organic matters deposited under reduced condition with a less effect of biodegradation and mature stage of occurrence. The gammacerane index indicated a low-salinity environment of deposition for the initial organic matters existed in the analyzed samples. Steranes distributions show high percentage of C28 steranes and C29 steranes compared with C27 steranes, and low-concentration C27 diasteranes show generally low ratios indicating anoxic carbonate source rocks. Th diasteranes/steranes showed generally low ratios indicating most marine carbonate sources. The tricyclic terpane reflects mature organic matters and originated from marine organic sources.

The objectives of this paper are providing a level of contamination of superficial coastal sediments by hydrocarbons from the coastal zone of the Suez Gulf through the evaluation of aliphatic and alicyclic hydrocarbons analyses using capillary column and gas chromatography. The locations were selected to cover about 18.7 km from the Suez Gulf coast taking into consideration the expected polluted area due to industrial and human activities. The results showed that the three levels of Suez Gulf was classified as highly polluted concentration in sediments and was categorized into four levels (guideline μg/g): unpolluted area/natural background level (10–15), slightly polluted area/upper permissible limits (15–50), and moderately polluted area (50–200). Therefore, the anthropogenic hydrocarbon inputs were more apparent at sites associated with industrial discharges (petroleum distributor and refinery), shipping activities (dry docking), and sewage outfalls (sewage); in addition, the chronic oil pollution in the area may be due to the large quantities of refined products and the limited capabilities of water treatment units located in the study area.

Specific geochemical analyses included API gravity, sulfur content, gas chromatography, and the advanced gas chromatography-mass spectrometry for biomarker distributions, in conjunction with stable carbon isotope geochemistry, to characterize the depositional environmental conditions and maturation assessment of the studied crude oils. For this purpose ten crude oils were collected from Miocene, Upper Cretaceous, and Nubia Sandstone representing the central-southern Gulf of Suez. The results showed that two different oil types identified as Miocene oils are characterized by a dominant oleanane and low gammacerane biomarkers, suggesting an overall angiosperm land plants input of terrigenous organofacies source rock. Pre-Miocene oils are distinguished by a dominant gammacerane and low oleanane biomarker distributions, which may be generated from fully mature marine carbonate source rocks. The higher sterane isomerization parameters, C29αßß/(αßß + ααα) and C29 ααα 20S/(S+R), further support the higher thermal maturation level for the Pre-Miocene oils rather than the Miocene type.

The geochemical analyses of Specific gravity (API), sulfur content, nickel and vanadium, porphyrins, bulk compositions, and saturated fraction obtained from gas chromatography have been studied with the aim of throwing more light on the geochemical aspects of the crude oil formation, migration, and maturation. Seven samples were collected from Sudr, October, GS-283, Belayim land, Belayim marine, Kareem, and July oilfields in the Gulf of Suez. These samples are representative for the producing horizon zones of Rudeis and Nuhkul formations of Middle-Lower Miocene age ranging in depths from 1344 to 3558 m. The studied crude oils are classified into heavy and/or intermediate oils. The crude oils have high concentrations of nickel and vanadium contents. Vanadyl porphyrins indicate mature to moderately mature oils. A gross composition reveals marine organic sources. The n-alkanes and isoprenoids in crude oils are derived from marine organic matter, deposited under anoxic/hypersaline to oxic or carbonate environments associated with evaporate and carbonate depositional environment.

The present work deals with isopach, lithofacies changes, and source rock chracteristics of Khatatba and Alam El Bueib formations of some wells in North East Western Desert. Isopach and lithofacies changes showed that the thickness of Khatatba Formation increases toward the south western direction and decreases toward northern parts, and the sediments consisting of sandstone and shale facies indicate a shallow marine environment. Alam El-Bueib sediments increase toward the north direction, and argillaceous sandstone facies reflect terrestrial-to-shallow marine environment. The geochemical analysis showed that Khatatba Formation bears a mature source rock and has poor-to-good generating capability for both oil and gas and lie within the early generation window and oil window. Alam El Buieb Formation constitutes a mature source rock and has poor-to-good generating capability for both oil and gas. It can be stated that Khatatba and Alam El Buieb are the main source rock for hydrocarbon accumulations rich with organic sediments and could be considered as effective source rocks for generating hydrocarbons in the the studied wells.

Poly-aromatic hydrocarbons (PAHs) were analyzed in sediments collected from the Suez Gulf to evaluate the composition, sources, and ecological risk assessment. The highest concentration of total PAHs is recorded in sediments collected from Inlet of Suez Oil Petroleum Company (SOPC), followed by east of the Outlet of SOPC and Outlet of SOPC. While lower concentrations of total PAHs are detected in Suez Beach west of the Outlet of SOPC, from Inlet of Al-Nasr Petroleum Company (NPC). The ratio of ∑LPAHs/∑HPAHs was <1, revealing their pyrogenic sources. The concentration levels of PAHs in the current study were compared to the effect range low (ERL) and the effect range medium (ERM) values for all investigated stations was below the ERL except for Inlet of SOPC. This finding indicated that PAHs in the surface sediments of the studied area have adverse biological effects, which may cause severe adverse biological and acute effects. The high levels of BaP equivalent (BaPE) values east of the Outlet of SOPC indicate that PAHs have relatively high toxicity among all sites. The toxic equivalent (TEQcarc) values of the sediment samples varied from 0.1883 to 1449.286 ng/g TEQ, with the mean value of 144.295 ng/g TEQ; the higher total TEQcarc values were found at 50 m east of the Outlet of SOPC: 1449.286 ng/g TEQ.

This work has provided important data about PAH concentrations, distribution, the potential risks and sources sediments of the Suez Gulf, Egypt. A geological study demonstrated that the sediments in the studied area have total PAH concentration (16 PAHs) varied from 6.6009 – 9442.803 ng/g dry weight, with the mean value of 1157.9793 ng/g dry weight in surficial sediments. The levels of PAHs in surface sediment were comparable to those found in many other marine systems, at some stations were relatively high in comparison to other urbanized coastal areas worldwide. The PAH distribution profile in the investigated area indicated potential source dependence, as the levels were generally higher in the vicinity of marinas, harbors and petroleum Companies. In accordance with our expectations higher concentrations were recorded in semi-enclosed areas such harbors and marinas as a result of more intense pollution and higher accumulation of pollutants. The PAH group profile shows the predominance of 6 ring PAHs and 4-5 ring PAHs. Among the individual PAH compounds identified, the most abundant PAH compounds perylene. The presence of relative high content of perylene in in surface sediments indicated terrestrial inputs of hydrocarbons. High levels of PAHs were reported in 50 m East the Outlet of Suez Oil petroleum Company and Inlet of Suez Oil Petroleum Company (SOPC) stations, with comparable to the rest of samples. Ratio between low molecular weight of PAHs (2- and 3-rings) to high (4- to 6-rings) has been used to differentiate between the pyrogenic and petrogenic sources of PAHs in the studied samples. Risk assessment of PAHs was performed by the BaPE values method. The results obtained showed that there is risk in some studied locations. Results obtained led to understand the potential risks and sources of PAHs in the Suez Gulf coasts, and to provide more information for protecting human health and water resources in this region. Regular monitoring of the Suez Gulf shore area studied is suggested in order to determine if any dumping activities have occurred in this area. Polycyclic aromatic hydrocarbons (PAHs) were analyzed in sediments collected from the Suez Gulf Egypt revealed that: 1. ∑PAH concentrations were in the range of 6.6009 – 9442.803 ng/g dry weight, with the mean value of 1157.9793 ng/g dry weight. 2. The highest concentration of total PAHs is recorded in sediments collected from Inlet of Suez Oil Petroleum Company (SOPC) 9442.803 ng/g dry weight, followed by that in 50 m East the Outlet of Suez Oil petroleum Company (SOPC) 5183.466 ng/g dry weight and Outlet of Suez Oil petroleum Company (SOPC) 1770.3265 ng/g dry weight; while lower concentrations are detected in Suez Beach 6.6009 ng/g dry weight, 600 m West the Outlet of Suez Oil Petroleum Company (SOPC), 300 m from Inlet of AL-Nasr Petroleum Company (NPC) and EL- Sukhna of Loloha Beach (16.8135, 47.4581and 65.0644 ng/g dry weight, respectively). 3. In this context, ratio of low molecular weight of PAHs (2- and 3-rings) to high (4- to 6-rings) has been used to differentiate between the pyrogenic and petrogenic sources of PAHs in the studied samples. 4. In all studied stations, ∑LPAHs/∑HPAHs ratios were <1, revealing their pyrogenic sources, except at EL- Sukhna of Loloha Beach recorded >1 suggested petrogenic source. The concentration levels of PAHs in the current study were compared to the effect range low (ERL) and the effect range medium (ERM) values; the average concentration of level of PAHs for all investigated stations was below the ERL except Inlet of Suez Oil Petroleum Company (SOPC) which recorded PAHs higher than both the ERL and ERM from Benzo [K] Fluoranthene (Bkf) and Benzo [ghi] perlyene (Bp). This finding indicated that PAHs in surface sediments of the studied area have adverse biological effects which may cause high adverse biological effects and acute effects. On the other hand, the station at 50 m East the Outlet of Suez Oil petroleum Company (SOPC) exhibit PAHs higher than the ERL but still lower than the ERM from Benzo [a] Pyrene (BaP) and Dibenzo [a,h] anthracene (DahA). To assess the Ecological risk assessment of PAHs; the BaP equivalent (BaPE) is used. High levels of BaPE values were found at 50 m east the Outlet of Suez Oil petroleum Company (SOPC) only, indicating that: 1. PAHs in this site showed relatively high toxicity among all sites. 2. Toxic equivalency factors (TEFs) of seven carcinogenic PAHs (BaA, BbF, BkF, BaP, Chr, DahA and IP), were used to quantitatively assess the potential toxicological significance to human health. In this study, the toxic equivalent (TEQcarc) values of sediment samples varied from 0.1883 to 1449.286 ng/g TEQ, with the mean value of 144.295 ng/g TEQ, the higher total TEQcarc values were found at 50 m East the Outlet of Suez Oil petroleum Company (SOPC) 1449.286 ng/g TEQ.

The organic matters of Rudeis and Kareem formation from Ras Budran oilfield in the central Gulf of Suez, Egypt, were investigated throughout the study of biomarkers and infrared spectrometric analyses. The results showed that Pr/Ph, Pr/n-C17, and Ph/n-C18 ratios indicated marine source organic matters deposited under reduced condition with a less effect of biodegradation and mature stage of occurrence. The gammacerane index indicated a low-salinity environment of deposition for the initial organic matters existed in the analyzed samples. Steranes distributions show high percentage of C28 steranes and C29 steranes compared with C27 steranes, and low-concentration C27 diasteranes show generally low ratios indicating anoxic carbonate source rocks. The diasteranes/steranes showed generally low ratios indicating most marine carbonate sources. The tricyclic terpane reflects mature organic matters and originated from marine organic sources.

Total organic carbon (TOC) and pyrolysis analysis of the Cretaceous and Miocene source rocks in the central Gulf of Suez were evaluated throughout the 25 rock samples collected from 6 formations, namely Wata, Raha, Nubia " A " (Cretaceous source rocks); and Nukhul, Zeit, and Belayim (Miocene source rocks) from Gharib-252, Gharib-153, Gharib-163, Gharib-164, Gharib-167, and Gharib-165 wells. These data are used to study the probabilities of the source rock in the Cretaceous and Miocene source rocks in the central Gulf of Suez for the hydrocarbon generation through identifying the organic richness, type of organic matters, and thermal maturation of these organic materials. The results revealed that the Cretaceous formations are immature source rocks, ranging from fair to good source rocks and have kerogen of type III and type III/II. Meanwhile, Miocene source rocks, ranging from immature to marginally mature source rocks, are considered to range from good to very good source rocks for potential generation of both oil and gas and are characterized by kerogen of type III/II and type II.

Organic matters from the KK 85-1and HH 83-1wells in the Central Gulf of Suez were analyzed by two well-proven organic geochemical methods: Rock-Eval pyrolysis and gas chromatography–mass spectrometry (GC–MS) analyses. These techniques were used to obtain independent parameters of organic matter composition, thermal maturity, and environment of deposition. The study reveals a close concordance between Rock-Eval pyrolysis data and biomarkers parameters such as steranes and triterpanes. Rock-Eval pyrolysis in conjunction with GC–MS analyses shows that the organic matters contain two types of kerogen (Type-II/III and Type III), which lie dominantly prior to the peak stage of the conventional oil window (end of diagensis–beginning of catagensis). The case study shows that these methods are suitable for a proper assessment of the petroleum potential of source rocks and the rapid geochemical characterization of sedimentary organic matter.

The gas chromatography (GC) and gas chromatography–mass spectrometry (GC-MS) analyses for crude oils from Kareem reservoir in the wells El Hamed-1, 3, and 5 are used to provide information on source organic matters input, depositional environment, and maturation level. Data include normal alkane and acyclic isoprenoids distribution, terpane, and sterane aliphatic biomarkers. Pristine/phytane (Pr/Ph), Pr/nC17, and Ph/nC18 ratios indicated mixed organic sources of organic matters (kerogen type II, III) dominantly (kerogen type III) with a less effect of biodegradation and mature stage of occurrence. The diasteranes/steranes ratio showed generally low ratios as in most marine carbonate sources, while algal-bacterial organic matter contribution for the oil samples suggested dependence on the predominance of C23 tricyclic terpane relative to the C19 tricyclic terpane, and the C25 tricyclic terpane greater than C24 tricyclic terpane. The gammacerane index indicated that a low-salinity environment of deposition for the initial organic matters existed in the analyzed samples.

The present work aims to using the application of GC, GC/MS, UV, and FT/IR spectroscopy organic matters extracted from sedimentary hydrocarbons from six coastal stations located in the Gulf of Suez and proposed to evaluate hydrocarbons in the sediments. The results the origins of hydrocarbons are multiple sources from terrestrial inputs, biogenic, and pyrolytic. Abundance of vascular plant n C23– n C33 alkanes with a high odd-to-even predominance, pristane, and phytane beside nC29/nC17 ratios and the presence of biogenic hopanes indicate the predominance of biogenic in combination with petrogenic hydrocarbons. FT-IR spectroscopic analysis indicates high concentrations of aliphatic hydrocarbons as well as mono- and polynuclear aromatic hydrocarbons are useful tool in organic geochemistry studies. UV analysis for organic matters incorporated in sediments reveals that oil pollutants have considerable amounts of aromatic compounds.

This work provides data on hydrocarbon contamination of 17 superficial sediments collected in the Suez Gulf. Non-aromatic hydrocarbons (NAH) were analyzed by FT/IR, UV and GC/MS. This fraction constitutes the predominant part of crude oils. It contains various hydrocarbon moieties such as n-alkanes, isoprenoids, Steranes and Terpanes which distributions permit to assess the various origins of hydrocarbons. This study can be seen as a complement of the work already conducted along Suez Gulf. The objectives of this paper are as follows: • provide a budget of the level of contamination of superficial coastal sediments by hydrocarbons for the North Western of Suez Gulf coasts; compare this level to other levels obtained from other sites from the world. Industrial effluent discharge and various oil exploration activities in the area are inevitable. The estuaries located in this area also receive organic pollutants from a number of diverse sources including municipal and domestic sewage. The results showed that the hydrocarbons are originated from multiple terrestrial inputs, biogenic, pyrolytic. Several ratios hydrocarbons indicated the predominance of petrogenic in combination with biogenic hydrocarbons. AL-Atka harbor, Suez oil processing company, Al–Nasr Oil Company, AL-Kabanon and EL- Sukhna of Loloha beach are the main source of contamination is petroleum. In summary, Lake Taihu surficial sediments showed different levels and sources of aliphatic hydrocarbons, and biomarkers and related indices can provide information on anthropogenic contamination, especially related to petrogenic sources, as well as recent biogenic materials. Near urban (e.g., Wuxi and Changzhou) and riverine (e.g., Zhihugang and Liangxihe) discharges, anthropogenic petrogenic AHC inputs were predominant. This was supported by: (1) high Org-C-normalized AHC concentrations; (2) significant contributions of UCM; (3) low n-alkane CPI and OEP; and (4) the high degree of maturity of hopane biomarkers. On the contrary, East Taihu sediments exhibited: (1) the lowest level of AHCs; (2) negligible or no contributions of UCM; (3) high n-alkane CPI and OEP; and (4) low degree of maturity of hopane biomarkers. These features suggested that AHCs in these sediments have a dominant biogenic (vascular plants) origin. Biomarker parameters for Western Basin sediment samples, however, indicated the predominance of biogenic in combination with petrogenic hydrocarbons. Information on sources and spatial variations of AHCs, together with other micropollutants, such as PAHs and heavy metals, may be useful in designing future strategies for protection and management of Lake Taihu.

The semienclosed Suez Gulf records various signals of high anthropic pressures from surrounding regions and the industrialized Suez countries. The sedimen-tary hydrocarbons have been studied in six coastal stations located in the Gulf of Suez. Nonaromatic hydrocarbons were analyzed by GC/FID and GC/MS to assess organic content in surface sediments of Suez Gulf, Egypt, depending on alkane, terpane, and sterane biological marker indicators. The results showed that the hydrocarbons are originated from multiple terrestrial inputs, biogenic and pyrolytic. Several ratios hydrocarbons indicated the predominance of pet-rogenic in combination with biogenic hydrocarbons.

Total organic carbon (TOC) and pyrolysis analysis of the Cretaceous and Miocene source rocks in the central Gulf of Suez were evaluated throughout the 25 rock samples collected from 6 formations, namely Wata, Raha, Nubia " A " (Cretaceous source rocks); and Nukhul, Zeit, and Belayim (Miocene source rocks) from Gharib-252, Gharib-153, Gharib-163, Gharib-164, Gharib-167, and Gharib-165 wells. These data are used to study the probabilities of the source rock in the Cretaceous and Miocene source rocks in the central Gulf of Suez for the hydrocarbon generation through identifying the organic richness, type of organic matters, and thermal maturation of these organic materials. The results revealed that the Cretaceous formations are immature source rocks, ranging from fair to good source rocks and have kerogen of type III and type III/II. Meanwhile, Miocene source rocks, ranging from immature to marginally mature source rocks, are considered to range from good to very good source rocks for potential generation of both oil and gas and are characterized by kerogen of type III/II and type II.

Total organic carbon (TOC) and pyrolysis analysis of the Cretaceous and Miocene source rocks in the central Gulf of Suez were evaluated throughout the 25 rock samples collected from 6 formations, namely Wata, Raha, Nubia 10 “A” (Cretaceous source rocks); and Nukhul, Zeit, and Belayim (Miocene source rocks) from Gharib-252, Gharib-153, Gharib-163, Gharib-164, Gharib-167, and Gharib-165 wells. These data are used to study the probabilities of the source rock in the Cretaceous and Miocene source rocks in the central Gulf of Suez for the hydrocarbon generation through identifying 15 the organic richness, type of organic matters, and thermal maturation of these organic materials. The results revealed that the Cretaceous formations are immature source rocks, ranging from fair to good source rocks and have kerogen of type III and type III/II. Meanwhile, Miocene source rocks, ranging from immature to marginally mature source rocks, are considered to range 20 from good to very good source rocks for potential generation of both oil and gas and are characterized by kerogen of type III/II and type II.

The quantity and thermal maturity of organic matter in the present study are discussed throughout the Rock-Eval pyrolysis for 27 rock samples of Tut -1x well used to describe the quantity, type, maturity, and petroleum generative potentials of prospective source rock horizons. The results showed that Alam El Bueib Formation has type-III kerogen. Masajid, Khatatba, and Ras Qattara Formations display mixed kerogen type II-III, which has the ability to generate mixed oil and gas accumulations under thermal maturation. Meanwhile, Alam El Bueib and Masajid Formations entered the early mature stage of oil generation at vitrinite reflectance values of 0.60 Ro%. The source rock of the Khatatba and Ras Qattara Formations reached to the peak of oil generation at vitrinite reflectance values of 1.36 Ro%. This indicates that Khatatba and Ras Qattara Formations can be consider to have generative potentials of prospective source rock horizons in the Tut-1x well.

The authors aimed to examine a multivariate statistical analysis approach for monitoring the hydrocarbon potentiality of source rocks in the North Western Desert to recognize the potentiality of source rocks and subsequently investigate the maturation level of the proven potential source formations for oil preservation. To achieve this aim, they applied multivariate statistics analysis (principle component analysis [PCA], cluster analysis, and correlation coefficient) and Rock-Eval pyrolysis analyses. The results showed that both PCA and cluster analyses have showed two types of source rocks. The first is classified as poor to fair source rock and immature to marginally mature source rock, the second is considered as fair to good source rock and mature to post mature source rock. PCA extracted two independent factors, which explained 81.87% of the total variance. The first type of source rock was responsible for 50% of the total variance and was best represented by variables TOC, S2, OI, and R o , and the second one was responsible for 31.65% of the total variance and was represented by the HI variable. Pearson correlation coefficient showed a significant positive correlation between TOC and S2 or R o. A positive correlation between S2 and HI or OI and also between OI and R o was observed, while no significant correlation was noticed between HI and R o .

Different analytical techniques, including API gravity; sulfur–nickel– vanadium contents; liquid chromatographic separation; and gas chromatography, were utilized to investigate oil families of three crude oils collected from Bakr oilfield of middle-lower Miocene age and characterized by limestone facies at various depth locations in the central Gulf of Suez. These geochemical aspects were used to assess source input and maturation of oil families. The results showed that the studied oils indicate a close genetic relationship between studied crude oils, and classified as aromatic intermediate oils. These types of oils are characterized by mature sources derived mainly from marine inputs such as biomass from algae and plankton from different saline environments.

The aim of this paper is to define the source rock potential of hydrocarbon generation through the determination of: (1) the quantity of organic matter, (2) present day kerogen types, (3) thermal maturity and (4) source organic matter input and depositional conditions of the source rock from Kareem, Rudeis and Matulla Formations, and Nubia Sandstone in 2 wells namely GH 376-1 and GH 404-1 throughout pyrolysis, vitrinite reflectance measurements and gas chromatographic analyses. The results suggest that Kareem and Rudeis source rocks have poor to good generating potential to generate both gas and oil at optimum maturity, Matulla source has a very good while Nubia has poor generating potential to generate both oil and gas at optimum maturity. The organic matter of Kareem, Rudeis and Nubia source rocks was deposited in marine environment under reducing conditions, while Matulla Formation deposited in transition environments and tends to be of terrestrial rather than marine sources.

Three crude oil and three extract samples collected from three source rocks namely Bahariya, Alam El Bueib, and Khatatba Formations from the Egyptian productive wells namely: Bed 2-1, Bed-2, and AG-1 oil fields. The oils were analyzed geochemically, including sulfur content and API gravity. Capillary gas chromatographic analysis was applied on each saturated hydrocarbons from oils and extracts to assess the correlation between the crude oils and the potential source rocks in order to confirm the indigenous sources for the petroleum generation of studied oil fields. The results show that the oil samples are originated mainly from marine organic sources deposited in reducing environment. By correlation between the source rocks and crude oils, we show that there is a good correlation between the extracts of Alam El Bueib and Khatatba source rocks with crude oils; while the extracts of Bahariya source rock show no correlation with the studied samples. These evidences indicate that Alam El Bueib and Khatatba source rocks seem to act as a source and reservoirs for oil generation in the studied oil fields.

ABSTRACT Objective: The objective of this paper represents the first comprehensive survey of PAHs in seawater and provides important data on PAHs concentration and composition in Alexandria coastal seawater in order to provide a technical basis to evaluate and pursue pollution abatements in the coastal seawater by hygienic treatment of the industrial effluents before their drainage in the marine water coasts is highly recommended. Methods: PAHs identification and quantification in thirteen extracted oil was performed using HPLC (Perkin Elmer series 200) with photodiode array detector. Quantitative analysis of PAHs showed a concentration ranged from 8970.939 to 1254756.0ng/L with an average 323749.13ng/L which exceed the maximum admissible concentrations of PAHs (200 ng/L) for the water standard of European Union. Results: The results indicates that calculated diagnostic ratios suggested that the sources of PAHs at the majority of the studied area are derived primarily from pyrogenic sources from incomplete fuel combustion of the boats and vehicle engines with lesser amounts of PAHs contributed from petrogenic sources. Some stations displayed mixed sources in comparison to many other studied marine systems, the PAH concentrations detected at Alexandria area were considered be higher to pose health risks to aquatic bodies. Conclusions: Along the Mediterranean coast of Alexandria city, there are many areas with high activities of shipping and pleasure boating activities, incorporating numerous Harbors and marina.

The present work deals with isopach, lithofacies changes, and source rock characteristics of Khatatba and Alam El Bueib formations of some wells in North East Western Desert. Isopach and lithofacies changes showed that the thickness of Khatatba Formation increases toward the south western direction and decreases toward northern parts, and the sediments consisting of sandstone and shale facies indicate a shallow marine environment. Alam El-Bueib sediments increase toward the north direction, and argillaceous sandstone facies reflect terrestrial-to-shallow marine environment. The geochemical analysis showed that Khatatba Formation bears a mature source rock and has poor-togood generating capability for both oil and gas and lie within the early generation window and oil window. Alam El Buieb Formation constitutes a mature source rock and has poor-to-good generating capability for both oil and gas. It can be stated that Khatatba and Alam El Buieb are the main source rock for hydrocarbon accumulations rich with organic sediments and could be considered as effective source rocks for generating hydrocarbons in the the studied wells.

Organic Geochemistry is the outgrowth of the application of the principles and methods of organic chemistry to petroleum refining and petroleum geology. Plays important role in petroleum exploration, where it is provide good information about origin, migration, accumulation and alteration of petroleum the earth’s crust. This branch of science has attracted growing number of scientists over the last five decades

The source rock potentiality of Middle Jurassic–Lower Cretaceous source rocks in Meleiha area was investigated through total organic carbon (TOC), Ro%, and pyrolysis analysis for 38 cutting samples collected from six wells. Also, the geochemical burial history profile to estimate the timing of hydrocarbon generation and expulsion of source rocks was constructed. The result revealed that the main hydrocarbon of source rocks, for the Middle Jurassic (Khatatba Fm.), is mainly mature, and has good capability for producing oil till present time. Lower Cretaceous source rocks (Alam El Bueib Fm.) are mature, derived from mixed organic sources, and have fair to good capability to generate gas and oil. Kharita Formations immature source rocks originating from terrestrial origin and have poor to fair potential to produce gas.

Total organic carbon (TOC) and Rock-¬Eval pyrolysis for 27 rock samples and geochemical model of Alam El Bueib, Masajid, Khatatba and Ras Qattara formations from Tut-1x well in the Tut Oilfield, North Western Desert, Egypt were used to describe the source rock charactrastics and petroleum generative potentials of prospective source rocks, including quantity, type of organic matter, and their thermal maturity level. The results were then incorporated into basin modeling in order to improve our understanding of burial/thermal histories and hydrocarbon generation and expulsion from Jurassic-Cretacouse source rocks. The bulk geochemical results showed that Alam El Bueib and Ras Qattara formations contain Type-III kerogen, while the Masajid and Khatatba formations displaying generally contain mixed kerogen types II-III, which have the ability to generate mixed oil and gas accumulations under thermal maturation level. Vitrinite reflectance values of the Jurassic-Cretacouse source rocks range from 0.42 to 0.86% R, indicating sufficient thermal maturity for oil-generation. Meanwhile, the burial/thermal history models indicate that the Alam El Bueib and Masajid formations entered the early-mature stage of oil-generation during the Late Cretaceous till present-day and the peak oil-generation has not been reached yet. The source rock of the Khatatba and Ras Qattara formations reached to the peak-oil generation at vitrinite reflectance values of 0.76 Ro% between 110 to 77 mybp and maximum rates of oil have been generated during late Cretaceous–early Tertiary (100-58 mybp). The transformation ratio of the main phase of oil-generation varied from 25% to 65%. The modeled hydrocarbon expulsion evolution suggests that the timing of hydrocarbon expulsion from the Khatatba and Ras Qattara source rocks began in the early Tertiary (58 mybp) and persisted to present-day. This indicates that Khatatba and Ras Qattara formations can be consider as a generative potentials of prospective source rock horizons in Tut oilfield.

Fiviteen rock samples were subjected to a comprehensive organic geochemical studies aiming to evaluate potential source rocks, as well as, to predict the time of petroleum generation and expulsion of Kharita, Alam El Bueib and Khataba formations in some wells in Meleiha area. The study revealed the Kharita Fm. is immature and has fair potential to produce gas. The organic matter is derived from terrestrial origin. Alam El Bueib Fm. is mature with fair to good capability to producing mixed oil and gas. The organic matter is originated mainly from mixed organic sources. Khatatba Fm is characterized by mature and good potentiality for generating oil. The organic matter is derived mainly from marine origin. The geothermal profile revealed that, Kharita Formation reached only to the early stage of hydrocarbon generation and did not enter to the oil widow till present time. Alam El Bueib Fm. entered the oil window during Late Eocene time. Khatatba Fm. entered the oil window during Late Cretaceous. Consequently, Khatatba Fm. in Meleiha area can be considered as effective source rocks for generating both oil and gas.

The present work deals with isopach, lithofacies changes, and source rock chracteristics of Khatatba and Alam El Bueib formations of some wells in North East Western Desert. Isopach and lithofacies changes showed that the thickness of Khatatba Formation increases toward the south western direction and decreases toward northern parts, and the sediments consisting of sandstone and shale facies indicate a shallow marine environment. Alam El-Bueib sediments increase toward the north direction, and argillaceous sandstone facies reflect terrestrial-to-shallow marine environment. The geochemical analysis showed that Khatatba Formation bears a mature source rock and has poor-to-good generating capability for both oil and gas and lie within the early generation window and oil window. Alam El Buieb Formation constitutes a mature source rock and has poor-to-good generating capability for both oil and gas. It can be stated that Khatatba and Alam El Buieb are the main source rock for hydrocarbon accumulations rich with organic sediments and could be considered as effective source rocks for generating hydrocarbons in the the studied wells.

Fifteen rock samples were subjected to comprehensive organic geochemical studies aiming to evaluate potential source rocks as well as to predict the time of petroleum generation and expulsion of Kharita, Alam El Bueib, and Khataba Fms. in some wells in Meleiha area. The study revealed the Kharita Fm. is immature and has fair potential to produce gas. The organic matter is derived from terrestrial origin. Alam El Bueib Fm. is mature with fair to good capability of producing mixed oil and gas. The organic matter is originated mainly from mixed organic sources. Khatatba Fm. is mature and has good potentiality for generating oil. The organic matter is derived mainly from marine origin. The geothermal profile revealed that Kharita Fm. reached only the early stage of hydrocarbon generation and did not enter the oil widow till the present time. Alam El Bueib Fm. entered the oil window during Late Eocene time. Khatatba Fm. entered the oil window during Late Cretaceous. Consequently, Khatatba Fm. in Meleiha area can be considered as effective source rocks for generating both oil and gas.

The main objective of this work is to evaluate the petrophysical characteristics of Alam-El Bueib reservoirs (AEB-3E, AEB-3D, and AEB-3A) in North Western Desert, Egypt, where they are important targets in this area. Core plugs laboratory measurements (porosity and permeability) of about 275 core samples of these reservoirs in TUT-1X well are used to achieve reservoir petrophysical evaluation. The core data analysis involves the construction of histograms, relations, and statistical analysis for porosity and permeability of these reservoirs. The statistical analysis and histograms of AEB-3E porosity indicate a good to very good homogenous reservoir with mean values 16 and 18 % for helium and fluid summation porosities, respectively. The horizontal and vertical permeability are very good with mean values 835.5 and 429.25 md, indicating high-quality reservoir. The study of AEB-3D indicates good and heterogeneous reservoir with mean values 10 %, 80.66 and 59.28 md for porosity, horizontal, and vertical permeability, respectively. AEB-3A reservoir reflects a good to very good homogeneous porosity and very good to excellent permeability with mean values 14 %, 299.75 and 184.32 md for porosity, horizontal, and vertical permeability. Concerning the three reservoirs, the helium-fluid porosity relations and the horizontal-vertical permeability relations give positive trends with strong correlation coefficients ranging from 0.51 to 0.93 which give the ability to calculate one parameter from the other.

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The present work deals with the identification of the potential and generating capability of oil generation in the Jurassic source rocks in the Salam-3x well. This depending on the organo-geochemical analyses of cutting samples representative of Masajid, Khatatba and Ras Qattara formations, as well as, representative extract samples of the Khatatba and Ras Qattara formations. The geochemical analysis suggested the potential source intervals within the encountered rock units as follows: Masajid Formation bears mature source rocks and have poor to fair generating capability for generating gas (type III kerogen). Khatatba Formation bears mature source rock, and has poor to good generating capability for both oil and gas. Ras Qattara Formation constituting mature source rock has good to very good generating capability for both oil and gas. The burial history modeling shows that the Masajid Formation lies within oil and gas windows; Khatatba and Ras Qattara formations lie within the gas window. From the biomarker characteristics of source rocks it appears that the extract is genetically related as the majority of them were derived from marine organic matters sources (mainly algae) deposited under reducing environment and take the direction of increasing maturity and far away from the direction of biodegradation. Therefore, Masajid Formation is considered as effective source rocks for generating hydrocarbons, while Khatatba and Ras Qattara formations are the main source rocks for hydrocarbon accumulations in the Salam-3x well.