Fowzia Abdullah | Kuwait University (original) (raw)
Papers by Fowzia Abdullah
71st EAGE Conference and Exhibition incorporating SPE EUROPEC 2009, 2009
The Lower Cretaceous Minagish Formation in Kuwait is a principal carbonate oil reservoir in the s... more The Lower Cretaceous Minagish Formation in Kuwait is a principal carbonate oil reservoir in the southern oil fields. The formation has been investigated petrographically as well as some organic geochemical analyses using Rock-Eval pyrolysis method. The
Memoir 106: Petroleum Systems of the Tethyan Region
Abstract Kuwait has proven oil reserves and production from supergiant and giant fields that incl... more Abstract Kuwait has proven oil reserves and production from supergiant and giant fields that include the Greater Burgan (Burgan, Ahmadi, and Maqwa), Raudhatain, Sabriya, and Minagish fields. These fields are associated with very gentle oval anticlines interpreted as drape structures over deep-seated fault scarps or as growth structures related to halokinesis. These structures are generally very simple, consisting of a series of roughly parallel, anticlinal uplifts trending NNW-SSE, with a few having a more N-S to NNE-SSW trend. Reservoir rocks are found in the Jurassic Marrat, Sargelu, and Najmah Formations (carbonates), the Lower Cretaceous Ratawi and Minagish Formations (sandstones and carbonates), and the Middle Cretaceous Burgan and Wara Formations (sandstones), as well as the Mauddud and Mishrif Formations (carbonates). Depth of reservoirs range from 3680 m (12,073 ft) in the Middle Jurassic to 2000–3650 m (6561–11,975 ft) in the Lower Cretaceous and 1000–2570 m (3281–8432 ft) in the Middle Cretaceous. The most important reservoirs are the Lower and Middle Cretaceous sandstones, which are sealed by interbedded and overlying shales. Several Jurassic and Cretaceous limestone units form additional, but subordinate, reservoirs that are generally sealed by shales. Only the Upper Jurassic Gotnia salt and the overlaying Hith Anhydrite seem to act as a regional seal for Middle Jurassic limestone reservoirs. Proven and potential source rocks with high TOC values, characterized by a mixture of marine and terrestrial sapropelic organic matter, are present in the upper-Lower and Middle Jurassic and the Lower and Middle Cretaceous. Kerogens from these rocks fall between Type II and II–III. The maturity level and quality of the kerogen in the Makhul (Sulaiy) Formation suggests that they are the most likely source rocks for the Cretaceous reservoirs, and responsible for generating part of the oil which has accumulated in present structures. Source rock characteristics for the Jurassic succession vary and range from moderate to excellent TOC values in the Sargelu and Najmah Formations. Similarly, the Middle Jurassic succession potentially represents mature oil generation. Oil generation from Jurassic source rocks began in the Late Cretaceous at the time when structural traps had already started to form. The Makhul (Sulaiy) source rock entered the oil window during the Early Tertiary, whereas oil expulsion occurred throughout Tertiary time.
Marine and Petroleum Geology
Abstract Organic petrography and geochemical analyses of 72 core samples from the Minagish Format... more Abstract Organic petrography and geochemical analyses of 72 core samples from the Minagish Formation revealed vertical variations in oil composition between four wells from the Burgan, Maqwa, Minagish and Umm-Gudair fields. The Burgan Field has a homogeneous oil column while variations in oil column were recognized between fields. The thickest heavy oil column, 46 m, was identified in Minagish Field. GC and GC-MS of the light and intermediate parts of the oil indicates a similar oil type, with a common oil pool in all of the oil fields. Thus, the variation in the nature and distribution of the heavy fractions of the oil in the Minagish reservoir is not be related to the source rock, expulsion and/or oil migration, but related to changes that occurred after or during oil accumulation in the reservoir. The methods and the results of this study are useful for planning drilling specially in reservoirs with heavy oil intervals such as the Minagish reservoir.
PALEOZOIC SOURCE ROCKS IN KUWAIT- A PRELIMINARY STUDY F.H ABDULLAH1*, F. SHAABAN 2, F. KHALAF 3, ... more PALEOZOIC SOURCE ROCKS IN KUWAIT- A PRELIMINARY STUDY F.H ABDULLAH1*, F. SHAABAN 2, F. KHALAF 3, F. BAHAMAN4 and B. AKBAR5 1. Dept. Earth and Environmental Science, Kuwait University. Khaldyah. PO Box 5969 Safat. 13060 Kuwait 2. ffas60@yahoo.com 3. fikry_khalaf@hotmail.com 4. fatma_bahman@yahoo.com 5. Dept. Research and Technology, Kuwait Oil Company bhakbar@kockw.com *) Corresponding author: fozabd2008@gmail.com The Paleozoic petroleum system in the State of Kuwait belongs to the greater Paleozoic system of the Arabian-Iranian Basin, which is one of the most prolific petroleumproducing systems in the world. The current knowledge of the Paleozoic Petroleum Geology in Kuwait is still inadequate despite the many studies that have been undertaken throughout the region over many years. Recent studies on the gas from Early Mesozoic reservoir indicate that it is thermogeneic gas, which might be produced from deeper Paleozoic formations. This is a preliminary evaluation study on Paleozoic ...
Journal of Asian Earth Sciences
Carbonates and Evaporites, 2017
Geoderma, 2013
ABSTRACT Cavity-fill dolocretes within the palaeokarst zone of the Middle Eocene chertified dolom... more ABSTRACT Cavity-fill dolocretes within the palaeokarst zone of the Middle Eocene chertified dolomicrite Dammam Formation are exposed within a quarry located on the top of Al-Ahmadi ridge in southern Kuwait. They are characterised by the abundance of zoned and spherulitic dolomite. These dolocretes are formed by massive precipitation of primary dolomite into cavity-fill siliciclastics within phreatic groundwater conditions during arid to semi-arid period. Successive stages of karstification and dolocretisation are responsible for the development of two types of cavity-fill dolocretes, namely; mature and immature dolocretes. The association of diagenetic alunites with the cavity-fill dolocretes suggests that hydrocarbon seepage may have played a role in the development of these dolocretes. It is suggested that the occurrence of similar diagenetic setting within carbonate sequence may potentially affect their reservoir characteristics.
Arabian Journal of Geosciences, 2014
Alunite minerals occur as white powdery lumps and laminated coloured deposits within cavity and s... more Alunite minerals occur as white powdery lumps and laminated coloured deposits within cavity and solution channel infill of the palaeokarst zone of the Upper Eocene Dammam Formation. This formation is exposed in a quarry located on the Al Ahmadi ridge within the Greater Burgan oil field in southern Kuwait. Field occurrences and sedimentary structures of the alunite deposits were described. Collected samples were petrographically described, and their mineralogy and geochemistry were determined using X-ray diffraction and X-ray fluorescence, respectively. Microfabrics were investigated using SEM, revealing that they are primarily composed of fibrous alunogen (hydrous aluminium sulphate) and pseudo-cubical K-alunite (hydrous potassium aluminium sulphate). Their mode of occurrence suggests a hypogenetic origin, where sulphide gases associated with hydrocarbon gases reacted with an Al-rich solution leached from clay minerals and feldspars of the cavity-fill muddy sand sediments. The hydrocarbon gases may have seeped from subsurface petroliferous formations within the Greater Burgan oil field along vertical fractures. This study suggests that these acidic seeps may have played a role in the development of the palaeokarst zone of the Dammam Formation.
Journal of Petroleum Geology, 2001
Jurassic sedimentary rocks in Kuwait are generally assigned to the Marrat, Dhruma, Sargelu and Na... more Jurassic sedimentary rocks in Kuwait are generally assigned to the Marrat, Dhruma, Sargelu and Najmah Formations (mainly limestones and calcareous shales) and the overlying Hith and Gotnia Formations which are composed of anhydrites and evaporites. This paper reports the results of organic-geochemical analyses of Jurassic carbonate and shale samples recovered from ten wells in Kuwait. Analytical techniques included TOC analysis, elemental analyses of kerogen, density separation and petrographic analyses. The thermal history ofKuwait was modelled and calibrated with maturity indicators from the studied wells. The analytical results point to the presence of marine kerogen between Qpes 11 and III. Generally, the formations show amorphous rich sapropelic organic matter with high H/C ratios and low densities. Biodegradation of some samples resulted in elevated O/C ratios. The results of maturity studies indicate that most ofthe Jurassic Succession is mature, maturity differences being due to depth variations. Oil generation began in Late Cretaceous to Eocene time when structural traps had already been formed. Jurassic source rocks may therefore have supplied reservoir units in Kuwait. In particular, the Najmah Formation includes well-preserved amorphous marine algal type organic matter: The high TOC values and thermal maturity of this formation make it one ofthe most important potential sources of oil in Kuwait.
Organic geochemistry, 2002
A set of 18 Cretaceous rock samples from wells drilled in the Raudhatain and Minagish Oil Fields ... more A set of 18 Cretaceous rock samples from wells drilled in the Raudhatain and Minagish Oil Fields and 10 oil samples from Cretaceous reservoirs (Raudhatain, Bahra, Burgan and Minagish Oil Fields) were characterized using geochemical methods including compound-specific carbon isotope analyses of n-alkanes and isoprenoids. In addition, one oil (Miqua) from the Jurassic (Marat Formation) of the Great Burgan Oil Field was included in the study. Despite having high organic carbon content in some samples, the Burgan and Zubair formations and the Ratawi Shale Member, of Albian to Valanginian age, are not source rocks for the oils for several reasons, but primarily due to lack of correlation of molecular and isotope chemistry as well as a humic organic matter type. These results are consistent with the corresponding depositional conditions for these rocks, which are deltaic/estuarine in the Burgan Formation and littoral/ deltaic in the Zubair Formation. The Minagish and Sulaiy Formations of Late Jurassic to Cretaceous age appear to be potential source rock candidates based on their molecular and bulk isotope geochemistry. Detailed isotopic analysis using individual normal and isoprenoid C 15+ alkanes did not provide a good correlation between these possible source rocks and the oils. However, one sample from the Sulaiy Formation was found to be comparable to the oils. The oils belong to the same genetic family and were expelled from a source rock with a dominant carbonate lithology (e.g. the Sulaiy-Minagish Formations). These formations contain sulphur-rich, amorphous kerogen as observed in recent, shallow marine shelf deposits. The Miqua oil, which accumulated in the Jurassic Marat Formation reservoir, does not differ from the other oils in terms of genetic characteristics. This oil is the deepest and most mature of the set. Maturity assessment has not been possible using well-known parameters based on steranes, terpanes or methylphenanthrenes. However, sulphur-bearing aromatics, comprised of alkylated BT and DBT, show important variations. Parameters based on alkylated BT and DBT have been applied successfully as tools to evaluate maturity changes. Oil maturity was determined to be middle oil window, but has been found not to be related directly to the present depth of the reservoir. However, it has been established that within the same oil field, oil maturity increases with reservoir depth. Evaluation of these maturity characteristics may be related to major chronological events, especially major tectonic movements that have enabled oil to fill different reservoirs successively. The reconstruction of the most important phases, i.e. genesis and migration through active faults, will provide guidelines to understand the present-day maturity pattern of these oils.
A Tribute to Douglas James Shearman, 2010
Journal of Petroleum …, Jan 1, 1996
Large volumes of oil and gas are present in the Arabian-Iranian Basin; however, most petroleum-ge... more Large volumes of oil and gas are present in the Arabian-Iranian Basin; however, most petroleum-geological investigations here have concentrated on reservoirs and traps, and there have been few efforts to study potential source rocks. This paper evaluates possible source rocks within the Lower to Middle Cretaceous interval in Kuwait, which is one of the main oil-and gas-producing countries in this region.
71st EAGE Conference and Exhibition incorporating SPE EUROPEC 2009, 2009
The Lower Cretaceous Minagish Formation in Kuwait is a principal carbonate oil reservoir in the s... more The Lower Cretaceous Minagish Formation in Kuwait is a principal carbonate oil reservoir in the southern oil fields. The formation has been investigated petrographically as well as some organic geochemical analyses using Rock-Eval pyrolysis method. The
Memoir 106: Petroleum Systems of the Tethyan Region
Abstract Kuwait has proven oil reserves and production from supergiant and giant fields that incl... more Abstract Kuwait has proven oil reserves and production from supergiant and giant fields that include the Greater Burgan (Burgan, Ahmadi, and Maqwa), Raudhatain, Sabriya, and Minagish fields. These fields are associated with very gentle oval anticlines interpreted as drape structures over deep-seated fault scarps or as growth structures related to halokinesis. These structures are generally very simple, consisting of a series of roughly parallel, anticlinal uplifts trending NNW-SSE, with a few having a more N-S to NNE-SSW trend. Reservoir rocks are found in the Jurassic Marrat, Sargelu, and Najmah Formations (carbonates), the Lower Cretaceous Ratawi and Minagish Formations (sandstones and carbonates), and the Middle Cretaceous Burgan and Wara Formations (sandstones), as well as the Mauddud and Mishrif Formations (carbonates). Depth of reservoirs range from 3680 m (12,073 ft) in the Middle Jurassic to 2000–3650 m (6561–11,975 ft) in the Lower Cretaceous and 1000–2570 m (3281–8432 ft) in the Middle Cretaceous. The most important reservoirs are the Lower and Middle Cretaceous sandstones, which are sealed by interbedded and overlying shales. Several Jurassic and Cretaceous limestone units form additional, but subordinate, reservoirs that are generally sealed by shales. Only the Upper Jurassic Gotnia salt and the overlaying Hith Anhydrite seem to act as a regional seal for Middle Jurassic limestone reservoirs. Proven and potential source rocks with high TOC values, characterized by a mixture of marine and terrestrial sapropelic organic matter, are present in the upper-Lower and Middle Jurassic and the Lower and Middle Cretaceous. Kerogens from these rocks fall between Type II and II–III. The maturity level and quality of the kerogen in the Makhul (Sulaiy) Formation suggests that they are the most likely source rocks for the Cretaceous reservoirs, and responsible for generating part of the oil which has accumulated in present structures. Source rock characteristics for the Jurassic succession vary and range from moderate to excellent TOC values in the Sargelu and Najmah Formations. Similarly, the Middle Jurassic succession potentially represents mature oil generation. Oil generation from Jurassic source rocks began in the Late Cretaceous at the time when structural traps had already started to form. The Makhul (Sulaiy) source rock entered the oil window during the Early Tertiary, whereas oil expulsion occurred throughout Tertiary time.
Marine and Petroleum Geology
Abstract Organic petrography and geochemical analyses of 72 core samples from the Minagish Format... more Abstract Organic petrography and geochemical analyses of 72 core samples from the Minagish Formation revealed vertical variations in oil composition between four wells from the Burgan, Maqwa, Minagish and Umm-Gudair fields. The Burgan Field has a homogeneous oil column while variations in oil column were recognized between fields. The thickest heavy oil column, 46 m, was identified in Minagish Field. GC and GC-MS of the light and intermediate parts of the oil indicates a similar oil type, with a common oil pool in all of the oil fields. Thus, the variation in the nature and distribution of the heavy fractions of the oil in the Minagish reservoir is not be related to the source rock, expulsion and/or oil migration, but related to changes that occurred after or during oil accumulation in the reservoir. The methods and the results of this study are useful for planning drilling specially in reservoirs with heavy oil intervals such as the Minagish reservoir.
PALEOZOIC SOURCE ROCKS IN KUWAIT- A PRELIMINARY STUDY F.H ABDULLAH1*, F. SHAABAN 2, F. KHALAF 3, ... more PALEOZOIC SOURCE ROCKS IN KUWAIT- A PRELIMINARY STUDY F.H ABDULLAH1*, F. SHAABAN 2, F. KHALAF 3, F. BAHAMAN4 and B. AKBAR5 1. Dept. Earth and Environmental Science, Kuwait University. Khaldyah. PO Box 5969 Safat. 13060 Kuwait 2. ffas60@yahoo.com 3. fikry_khalaf@hotmail.com 4. fatma_bahman@yahoo.com 5. Dept. Research and Technology, Kuwait Oil Company bhakbar@kockw.com *) Corresponding author: fozabd2008@gmail.com The Paleozoic petroleum system in the State of Kuwait belongs to the greater Paleozoic system of the Arabian-Iranian Basin, which is one of the most prolific petroleumproducing systems in the world. The current knowledge of the Paleozoic Petroleum Geology in Kuwait is still inadequate despite the many studies that have been undertaken throughout the region over many years. Recent studies on the gas from Early Mesozoic reservoir indicate that it is thermogeneic gas, which might be produced from deeper Paleozoic formations. This is a preliminary evaluation study on Paleozoic ...
Journal of Asian Earth Sciences
Carbonates and Evaporites, 2017
Geoderma, 2013
ABSTRACT Cavity-fill dolocretes within the palaeokarst zone of the Middle Eocene chertified dolom... more ABSTRACT Cavity-fill dolocretes within the palaeokarst zone of the Middle Eocene chertified dolomicrite Dammam Formation are exposed within a quarry located on the top of Al-Ahmadi ridge in southern Kuwait. They are characterised by the abundance of zoned and spherulitic dolomite. These dolocretes are formed by massive precipitation of primary dolomite into cavity-fill siliciclastics within phreatic groundwater conditions during arid to semi-arid period. Successive stages of karstification and dolocretisation are responsible for the development of two types of cavity-fill dolocretes, namely; mature and immature dolocretes. The association of diagenetic alunites with the cavity-fill dolocretes suggests that hydrocarbon seepage may have played a role in the development of these dolocretes. It is suggested that the occurrence of similar diagenetic setting within carbonate sequence may potentially affect their reservoir characteristics.
Arabian Journal of Geosciences, 2014
Alunite minerals occur as white powdery lumps and laminated coloured deposits within cavity and s... more Alunite minerals occur as white powdery lumps and laminated coloured deposits within cavity and solution channel infill of the palaeokarst zone of the Upper Eocene Dammam Formation. This formation is exposed in a quarry located on the Al Ahmadi ridge within the Greater Burgan oil field in southern Kuwait. Field occurrences and sedimentary structures of the alunite deposits were described. Collected samples were petrographically described, and their mineralogy and geochemistry were determined using X-ray diffraction and X-ray fluorescence, respectively. Microfabrics were investigated using SEM, revealing that they are primarily composed of fibrous alunogen (hydrous aluminium sulphate) and pseudo-cubical K-alunite (hydrous potassium aluminium sulphate). Their mode of occurrence suggests a hypogenetic origin, where sulphide gases associated with hydrocarbon gases reacted with an Al-rich solution leached from clay minerals and feldspars of the cavity-fill muddy sand sediments. The hydrocarbon gases may have seeped from subsurface petroliferous formations within the Greater Burgan oil field along vertical fractures. This study suggests that these acidic seeps may have played a role in the development of the palaeokarst zone of the Dammam Formation.
Journal of Petroleum Geology, 2001
Jurassic sedimentary rocks in Kuwait are generally assigned to the Marrat, Dhruma, Sargelu and Na... more Jurassic sedimentary rocks in Kuwait are generally assigned to the Marrat, Dhruma, Sargelu and Najmah Formations (mainly limestones and calcareous shales) and the overlying Hith and Gotnia Formations which are composed of anhydrites and evaporites. This paper reports the results of organic-geochemical analyses of Jurassic carbonate and shale samples recovered from ten wells in Kuwait. Analytical techniques included TOC analysis, elemental analyses of kerogen, density separation and petrographic analyses. The thermal history ofKuwait was modelled and calibrated with maturity indicators from the studied wells. The analytical results point to the presence of marine kerogen between Qpes 11 and III. Generally, the formations show amorphous rich sapropelic organic matter with high H/C ratios and low densities. Biodegradation of some samples resulted in elevated O/C ratios. The results of maturity studies indicate that most ofthe Jurassic Succession is mature, maturity differences being due to depth variations. Oil generation began in Late Cretaceous to Eocene time when structural traps had already been formed. Jurassic source rocks may therefore have supplied reservoir units in Kuwait. In particular, the Najmah Formation includes well-preserved amorphous marine algal type organic matter: The high TOC values and thermal maturity of this formation make it one ofthe most important potential sources of oil in Kuwait.
Organic geochemistry, 2002
A set of 18 Cretaceous rock samples from wells drilled in the Raudhatain and Minagish Oil Fields ... more A set of 18 Cretaceous rock samples from wells drilled in the Raudhatain and Minagish Oil Fields and 10 oil samples from Cretaceous reservoirs (Raudhatain, Bahra, Burgan and Minagish Oil Fields) were characterized using geochemical methods including compound-specific carbon isotope analyses of n-alkanes and isoprenoids. In addition, one oil (Miqua) from the Jurassic (Marat Formation) of the Great Burgan Oil Field was included in the study. Despite having high organic carbon content in some samples, the Burgan and Zubair formations and the Ratawi Shale Member, of Albian to Valanginian age, are not source rocks for the oils for several reasons, but primarily due to lack of correlation of molecular and isotope chemistry as well as a humic organic matter type. These results are consistent with the corresponding depositional conditions for these rocks, which are deltaic/estuarine in the Burgan Formation and littoral/ deltaic in the Zubair Formation. The Minagish and Sulaiy Formations of Late Jurassic to Cretaceous age appear to be potential source rock candidates based on their molecular and bulk isotope geochemistry. Detailed isotopic analysis using individual normal and isoprenoid C 15+ alkanes did not provide a good correlation between these possible source rocks and the oils. However, one sample from the Sulaiy Formation was found to be comparable to the oils. The oils belong to the same genetic family and were expelled from a source rock with a dominant carbonate lithology (e.g. the Sulaiy-Minagish Formations). These formations contain sulphur-rich, amorphous kerogen as observed in recent, shallow marine shelf deposits. The Miqua oil, which accumulated in the Jurassic Marat Formation reservoir, does not differ from the other oils in terms of genetic characteristics. This oil is the deepest and most mature of the set. Maturity assessment has not been possible using well-known parameters based on steranes, terpanes or methylphenanthrenes. However, sulphur-bearing aromatics, comprised of alkylated BT and DBT, show important variations. Parameters based on alkylated BT and DBT have been applied successfully as tools to evaluate maturity changes. Oil maturity was determined to be middle oil window, but has been found not to be related directly to the present depth of the reservoir. However, it has been established that within the same oil field, oil maturity increases with reservoir depth. Evaluation of these maturity characteristics may be related to major chronological events, especially major tectonic movements that have enabled oil to fill different reservoirs successively. The reconstruction of the most important phases, i.e. genesis and migration through active faults, will provide guidelines to understand the present-day maturity pattern of these oils.
A Tribute to Douglas James Shearman, 2010
Journal of Petroleum …, Jan 1, 1996
Large volumes of oil and gas are present in the Arabian-Iranian Basin; however, most petroleum-ge... more Large volumes of oil and gas are present in the Arabian-Iranian Basin; however, most petroleum-geological investigations here have concentrated on reservoirs and traps, and there have been few efforts to study potential source rocks. This paper evaluates possible source rocks within the Lower to Middle Cretaceous interval in Kuwait, which is one of the main oil-and gas-producing countries in this region.