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Detailed geologic map of the Midyan Basin showing distribution of the Burqan formation outcrops (modified from Clark, 1986 and Hughes et al., 1999).
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The Early Miocene sandstone of the Burqan Formation from Midyan Basin is considered an oil-bearing unit. The outcrops of this sandstone, which are exposed in the northwestern part of the basin, have been studied through field and laboratory-based investigations. During the field work, 81 surface samples were collected for reservoir characterization...
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... thick marine siliciclastic succession of this formation is well exposed in the west of Jabal Rughama (flanking the Magna Massif) and along the Gulf of Aqaba coast (north and south of Magna village). In addition, this succession is also exposed in Wadi Al-Hamedh, which is approximately 30 km long and 18 km wide ( Figure 1). The Burqan Formation has been confirmed by Saudi Aramco in the exploration well AI-Wajh South-1 (AWSO-1) at a depth of 2875-3819 m, making it 944 m thick (Hughes and Johnson, 2005). ...
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... clay minerals also played an important role in controlling permeability and porosity in the Burqan sandstones. Stacked booklets of kaolinite were observed clearly in the SEM analysis (Figures 9A and 9B) and were confirmed by XRD analyses (Figure 10), which could be counted as a significant constituent in determining a reservoir quality. Various individual kaolinite booklets, which have no preferred orientation relative to each other, occupied a large part of the original pore spaces, hence affecting the primary porosity. ...
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... kaolinite distribution in the central flow paths also played a role in reducing the permeability. The presence of smectite was confirmed by XRD analysis, which probably played a role in reducing porosity in the studied sandstone ( Figure 11). Based on these observations, the following conclusions can be made: ...
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This research work focuses attention on the Reservoir Characterization of a hydrocarbon bearing sand in 'Chioma' field of the Niger Delta. The environment of deposition is examined and the type produced as a model of the sub-surface reservoir. To achieve this, an integrated analysis of cores from wells, as well as biostratigraphic data and wireline...
Citations
... Şekil 3. A) Midyan Yarımadası'nın sadeleştirilmiş jeolojik haritası (Clark, 1986 The proven hydrocarbon potential of the sandstones and carbonates in the Midyan Basin has attracted the interest of various oil companies and Saudi universities. Many stratigraphic and sedimentologic sections have been measured in almost every part of the Midyan Peninsula as a sunbstantive framework for hydrocarbon explorations (Alsharhan and Nairn, 1997;Hughes and Johnson, 2005;Al-Ramadan et al., 2013;Al-Laboun et al., 2014;Şenalp, 2016). These hydrocarbon-bearing successions present an excellent opportunity to identify the influence of severe tectonic uplifting of the source areas on paleoclimates and the evolution of water depths, resulting depositional systems and basin filling as rifting progressed. ...
... These studies provided an important source of data to correlate them with oil producing reservoir facies in exploration wells in the Red Sea, Gulf of Suez and Midyan Basin (Alsharhan, 2003). They also greatly assisted in understanding the burial history and roles of different diagenetic processes on the reservoir properties, which can in turn be used to predict porosity and permeability of the subsurface reservoirs (Al-Ramadan et al., 2013;Al-Laboun et al., 2014;Şenalp, 2016). ...
The hydrocarbon-producing Midyan Basin is located in northwestern Saudi Arabia and is surrounded
by the Proterozoic igneous basement of the Arabian Shield. It includes thick hydrocarbon-producing sedimentary
sequences deposited in half-grabens that formed during rifting of the Red Sea and the gulfs of Suez and Aqaba
in the Early Miocene (23.3 Ma). The early syn-rift succession consists of arid alluvial fan sediments and playa
evaporates, followed by shallow marine carbonates. The late syn-rift sequences consist of progradational deep sea
turbidites and Alpine-type glacial deposits indicating strong vertical uplift during the climax of the rifting (19 Ma).
The post-rift succession overlies the late syn-rift successions and consist of shallow marine marls and evaporites.
The aim of this study is to examine the hydrocarbon potential of the turbidite sandstones and the formation of various
types of glacial deposits in the Burqan Formation. This study also encompasses the importance of various geologic
processes in order to understand their significant influence on the geometry, continuity and reservoir quality of oil
and gas producing genetically different sandstones in the subsurface of the Burqan Formation in the Midyan Basin.
The Alpine-type glacial deposits provide an excellent opportunity to study the presence of continuous vertical and
lateral facies variations between true glacial, glacio-fluvial and glacio-marine deposits in the direction of sediment
transportation. Unsorted moraines deposited in the deep and U-shaped glacial valleys occupy the northwestern part
of the basin. They pass gradually into glacio-fluvial sandstones that contain large polished and striated boulders. In
the southeastern part of the deep basin, the glacio-marine deposits are associated with deep sea turbidites and pelagic
shales. Many stratigraphic and sedimentologic sections were measured from well-exposed outcrops in every part
of the basin to establish various depositional environments. A large number of sandstone samples was collected to
examine their reservoir quality.
... The most important difficulty which needs a comprehensive understanding to enhance oil recovery is the reservoir heterogeneity. (Worden and Morad, 2000;Worden and Barclay, 2003;Ajdukiewicz and Lander, 2010;Morad et al., 2010;Al-Laboun et al., 2014;Worden et al., 2018). Reservoir heterogeneity is common problem in the African and Arabian equivalents of the Bedinan Formation, and mostly induced by the Hirnatian glacial activity (Lüning et al., 1999;Ghienne et al., 2007;Le Heron and Howard, 2010;Craigie et al., 2016;Senalp et al., 2018). ...
... Reservoir heterogeneity refers to the quality of variation in porosity, permeability and capillary pressure of a petroleum reservoir and has a major impact on fluid flow and oil recovery (Ajdukiewicz and Lander, 2010;Morad et al., 2010). Reservoir quality in sandstone facies is the cumulative product of depositional facies (grain size and morphology, sorting, sand/mud ratio, pore-water chemistry, sedimentary structures, degree of bioturbation, provenance), diagenetic processes (compaction, cementation, clay mineral development) and structural features (fracturing, fault etc.) (Worden and Morad, 2000;Worden and Barclay, 2003;Ajdukiewicz and Lander, 2010;Morad et al., 2010;Al-Laboun et al., 2014;Worden et al., 2018). Imaging the scale and extend of variation in reservoir quality is commercially important to make risk analysis and to determine the most efficient well stimulation strategies; however, remains a challenge. ...
... Şekil 3. A) Midyan Yarımadası'nın sadeleştirilmiş jeolojik haritası (Clark, 1986 The proven hydrocarbon potential of the sandstones and carbonates in the Midyan Basin has attracted the interest of various oil companies and Saudi universities. Many stratigraphic and sedimentologic sections have been measured in almost every part of the Midyan Peninsula as a sunbstantive framework for hydrocarbon explorations (Alsharhan and Nairn, 1997;Hughes and Johnson, 2005;Al-Ramadan et al., 2013;Al-Laboun et al., 2014;Şenalp, 2016). These hydrocarbon-bearing successions present an excellent opportunity to identify the influence of severe tectonic uplifting of the source areas on paleoclimates and the evolution of water depths, resulting depositional systems and basin filling as rifting progressed. ...
... These studies provided an important source of data to correlate them with oil producing reservoir facies in exploration wells in the Red Sea, Gulf of Suez and Midyan Basin (Alsharhan, 2003). They also greatly assisted in understanding the burial history and roles of different diagenetic processes on the reservoir properties, which can in turn be used to predict porosity and permeability of the subsurface reservoirs (Al-Ramadan et al., 2013;Al-Laboun et al., 2014;Şenalp, 2016). ...
Geological Bulletin of Turkey, 2020 (Accepted Paper)
... During the time of deposition, the sand particles develop a self-supporting framework forming a detrital matrix with pore spaces, which results in porosity and permeability (Ali et al., 2010). Permeability, in turn, is controlled by factors such as effective porosity, grain size, composition and structure of the rock and textural properties such as sphericity and sorting (Al-laboun et al., 2014). Furthermore, these controlling factors can be altered due to changes in depositional environments; thus, implying that a prudent interpretation of the depositional setting plays a vital role in assessing reservoir properties and the overall quality. ...
... Reservoir heterogeneity refers to relative variation in porosity, permeability and capillary pressure due to depositional facies, type and amount of matrix content, provenance, rate of deposition, the degree of compaction (mechanical and chemical), diagenetic impact, the time of oil emplacement, paleo-climate, structural deformations (fracturing, fault e.t.), thermal history of basin (Worden and Morad, 2000;Worden and Barclay, 2003;Ajdukiewicz and Lander, 2010;Morad et al., 2010;Al-Laboun et al., 2014;Worden et al., 2018). The heterogeneity of the reservoirs is responsible for variation in volume, hydrocarbon recovery from the reservoir and fluid flow rate (Morad et al., 2010). ...
... The relative variation in porosity, permeability and capillary pressure rates infers to reservoir heterogeneity and exerted great control on planning and determining well stimulation methods to increase hydrocarbon production rate, flow rate and recovery (Worden and Morad, 2000;Worden and Barclay, 2003;Ajdukiewicz and Lander, 2010;Morad et al., 2010;Al-Laboun et al., 2014, Worden et al., 2018. The scale and extent of reservoir heterogeneity ( Figure 54) are hosted in many questions and has still subjected to debate. ...
... Reservoir quality is characterised as a function of (i) depositional facies (sorting, grain size, grain morphology, sand/mud ratio, provenance, sedimentary structures) (ii) diagenesis (compaction, dissolution, cementation, development of clay coating minerals) (iii) structural features (fault, fracturing e.t.) (Worden and Morad, 2000;Worden and Barclay, 2003;Ajdukiewicz and Lander, 2010;Morad et al., 2010;Al-Laboun et al., 2014). Although depositional facies and compaction exerted a strong control on reservoir quality of the Bedinan Formation sandstone levels, in this study, reservoir heterogeneity is linked to eodiagenetic (early diagenetic) and dominantly mesodiagenetic (late diagenetic) clay coating minerals, quartz overgrowth and carbonate (calcite and dolomite) cement. ...
Recent high-quality oil discoveries in SE Turkey, specifically Diyarbakır Basin from the Ordovician aged Bedinan Formation sandstone reservoir levels have introduced many questions. The fact that variable hydrocarbon production rates in the studied wells oblige us to delineate internal framework of the sandstone levels and to find the answer for the reason of the reservoir heterogeneity which will be a proxy to find convenient well stimulation methods in order to increase hydrocarbon recovery.
In this study, Gazzi-Dickinson method of point counting on thin sections, X-ray computed tomography imaging technique, semi-quantitative X-ray diffraction (XRD) bulk powder mineral analysis, seismic lines, wireline log data, and available well data were used to understand the depositional environment, the paleogeography during the geological evaluation, the mineral framework and the provenance of the levels of interest. Additionally, petrophysical log interpretation via Petrel software together with regional stratigraphy and correlation studies were carried out to explain the reason and scale of the reservoir heterogeneity.
As a consequence of the studies, it is seen that the subarkose to quartz arenitic sandstone levels of the Bedinan Formation were deposited between the lower and
vi
upper shoreface of an ice-distal glaciomarine depositional environment. Additionally, the origin of sandstones are related to igneous and cratonic sources.
The most important result of this study on the reservoir heterogeneity of this sandstone levels of uppermost Bedinan Formation is that besides the depositional facies, structural features and compaction, particularly diagenetic clay coating minerals (illite, kaolinite and illite/smectite mixed clay layer) together with quartz and carbonate cements have exerted great control on the reservoir quality in meters scale, which results in variable hydrocarbon production rate.
... In terms of permeability, the studied sandstone of the McKee Formation is characterized by a wide range of permeability ranging from 1.5 to 1140 mD ( Figure 8). The permeability of the sandstone is generally dependent on the interconnectivity of porosity (effective), which is largely influenced by grain size and shape, the degree of sorting, grain packing, and the diagenetic processes [37][38][39]. ...
The Late Eocene onshore McKee Formation is a producing reservoir rock in Taranaki Basin, New Zealand. An integrated petrophysical, sedimentological, and petrographical study was conducted to evaluate the reservoir characteristics of the McKee sandstone. A petrographic study of the McKee Formation classified the sandstone as arkose based on the Pettijohn classification. Porosity analysis showed predominantly intergranular porosity, as elucidated by the thin section
photomicrographs. The good reservoir quality of McKee sandstone was suggested to be the result of
the presence of secondary dissolution pores interconnected with the primary intergranular network. Mineral dissolution was found to be the main process that enhanced porosity in all the studied wells. On the other hand, the presence of clay minerals, cementation, and compaction were identified as the main porosity-reducing agents. These features, however, were observed to occur only locally,
thus having no major impact on the overall reservoir quality of the McKee Formation. For a more detailed reservoir characterization, well log analysis was also applied in the evaluation of the McKee Formation. The result of the well log analysis showed that the average porosity ranged from 11.8% to 15.9%, with high hydrocarbon saturation ranging from 61.8% to 89.9% and clay volume content ranging from 14.9 to its highest value of 34.5%. Based on the well log analysis, the derived petrophysical and reservoir parameters exhibited good porosity, low clay content, and high hydrocarbon saturation, which indicates that the McKee Formation is a promising reservoir.
... Therefore investigations of diagenesis processes are necessary for understanding reservoirs quality. The goal of this study is survey of effect of diagenetic presses on reservoir properties and also flow unites determination in the Ilam Formation of Dezfol embayment using petrography evidence and petrophysics data (such as [14] [15], and many others). [16]. ...
Dezfol embayment in the Southwest of Iran is located in the Zagros fold-thrust belt, which is one of the world’s largest petroleum provinces. Ilam Formation (Santonian-Companian) is one of the reservoir formations in this area that has been less studied. This paper focused on reservoir properties in this formation using petrography and petrophysics data. According to the petrography studies Ilam Formation composed of limestone as dominant lithology. Detailed petrographic analyses, have led to identification of 10 micro-facies which are represented as a carbonate ramp depositional model. Also petrographic analyses are revealed that cementation, dissolution, compaction and dolomitization are most important digenetic processes. Detailed petrographic analyses and petrophysics data showed that due to mud-supported nature of more facies (inherited low reservoir potential from their depositional settings), diagenetic process plays an important role in increasing of reservoir quality. However cementation and dissolution had negative and positive effects on Ilam reservoir formation, respectively. Finally at the end for better correlation and to create a flow unit, according to the petrography data and using petrophysics log, this reservoir is divided into 5 units (flow unite) by using Geolog software and then they have been correlated across the field.
... It generally ranges from 0.1 to 1000 mD or more [3]. Permeability depends on effective porosity of rock, whereas, it is also controlled by composition, texture and structure of rocks [4]. Texture of sandstone is different due to variation in depositional environment, and it consists of grain size, sphericity, sorting, porosity, texture material and textural maturity of formation. ...
Permeability is the ability of formation to produce hydrocarbon which is affected by compaction, pore size, sorting, cementation, layering and clay swelling. The effect of texture on permeability in term of grain size, sorting, sphericity, degree of cementing has been reported in literature. Also, the effect of permeability on capillary pressure, irreducible water saturation, displacement pressure and pore geometry constant has been studied separately. This preliminary study presents the experimental results of eight samples to understand the effect of similar factors of texture on permeability. With the knowledge of the results, it can be said that the effect of grain size, cementation, texture material, sphericity, and porosity can't be observed on permeability except sorting when less than ten samples are considered from different depositional environment. The results also show the impact of permeability on capillary pressure, irreducible water saturation, and displacement pressure and pore geometry index as similar as published in the literature.
Carbon capture and storage (CCS) technologies are needed as a crucial technology for Saudi Arabia to reach its net-zero goal by 2060. This study represents the first comprehensive evaluation of geological CO2 storage capacities in the sedimentary basins of Saudi Arabia. Our study relied on collecting and analyzing hundreds of data sets from public domains, which were carefully selected based on their quality and relevance to ensure reliability.
We evaluated the suitability and storage capacity of 17 basins and sub-basins throughout the country for CO2 storage in deep saline aquifers as well as future depleted oil and gas reservoirs using the CO2-SCREEN tool. Our evaluation shows that the most suitable basins are located in the eastern part of the country, including the
Eastern Arabian Basin and the Interior Homocline-Central Arch. On the other hand, Western Saudi Arabia is characterized by less favorable basins, except for the three moderately suitable onshore basins, namely the Umm Luj, Yanbu, and Jeddah basins. Uncertainties were considered by performing Monte Carlo simulations. At the 50th percentile uncertainty, the estimated total effective storage capacities in deep saline aquifers, future
depleted oil reservoirs, and non-associated gas reservoirs are ~432, ~5, and ~ 9 gigatons (Gt), respectively.
Most of the country’s storage capacity is located in the eastern region, displaying an uneven distribution of storage resources nationally. For full transparency, we share all the calculation sheets utilized. The methodology adopted for estimating the potential capacity aligns with the effective storage capacities defined by the Carbon Sequestration Leadership Forum (CSLF). The capacity estimates account for technical, geological, and engineering constraints. Nevertheless, it is crucial to note that the practical storage capacity estimate requires the incorporation of additional societal, economic, and regulatory factors, which were not taken into consideration in this study. Consequently, there is a pressing need for additional research, particularly prospect-level evaluations entailing drilling, testing evaluation, and monitoring wells. These comprehensive investigations will significantly contribute to our comprehension of reservoir and seal characteristics, assess injectivity performance, and provide profound insights into CO2 behavior, effectively mitigating uncertainties. The storage capacity estimates presented in this study furnish crucial information for policymakers and industry leaders engaged in addressing carbon emissions in Saudi Arabia.
Siliciclastic sediments represent important lithological unit of the Red Sea coastal plain. Their subsurface equivalents are important targets of groundwater aquifer and hydrocarbon reservoirs in the region. The lithofacies of the modern fluvial deltaic system has several distinct geomorphic units and sub-environments such as alluvial, fluvial, delta plain, aeolian, intertidal, coastal sabkha and eustuarine sediments. This study intends to characterize the lithofacies and the depositional environments and to produce an integrated facies model for this modern fluvial-deltaic system. The study might provide a valuable modern analog to several important subsurface Neogene formations that act as important hydrocarbon reservoirs and groundwater aquifers. The study integrates information and data obtained from landsats, maps and detailed field observation and measurements of facies analysis of the fluvial and deltaic along traveses from the Arabian Shield to the Red Sea coast. The lithofacies sediment analysis revealed four main lithofacies associations namely lithofacies A,B,C ad D. Lithoacies Associations A, which represents the oldest unit is dominated by coarse gravel with minor sands facies. While the lithofacies B is dominated byfine gravel and sand lithofacies, occasionally pebbly, vary from horizontal, planar to massive sands with minor laminated to massive silts and mud facies. The lithofacies in A and B show lateral proximal to distal variation as well as characteristic vertical stacking patterns. The Facies Association A and B indicates a change in fluvial depositional styles from gravelly alluvial fans to gravelly sandy fluvial systems. The lithofacies association C represents the recent fluvial system which consists of minor gravel lag deposits associated maily with various sand lithofacies of planner, horizontal and massive sand associated with massive and limainted sand and mud lithofacies. The lithofacies Association D is dominated with Barchan sand dunes local interfigger with muddy iinterdunes and sand sheets. Lithofacies D occupies rather more distal geomporphic position of the fluvial deltaic system that is adjace to coastal sabkha. The lithofacies associations described here document the evolution and development of the coastal plain sediments through space and time under various autocyclic and allocyclic controls. This included the tectonics and structural development associated with the Red Sea rifting and opening since the Oligocene – Miocene time. Others controls include the evolution of the Arabian shield (provenance) and the coastal plain through space and time as controlled by tectonics, sediment supply, climate and locally by autocyclic environmental This study might be beneficial for understanding the controls and stratigraphic evolution of the Red Sea region and will be of great value for reservoir and aquifer characterization, development and management. This modern analog model can also help in providing geological baseline information that would be beneficial for understanding similar ancient fluvial deltaic sediments. The study might provide guides and leads to understand the subsurface facies, stratigraphic architecture and heterogeneity of any potential groundwater aquifers and hydrocarbon reservoirs.
