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Scale up of porosity and water saturation for FQ-6. Petrophysical modeling process Petrophysical property modeling is the process of assigning petrophysical property values (porosity and water saturation) to each cell of the 3D grid. Petrel offers several algorithms for modeling the distribution of petrophysical properties in a reservoir model. Petrophysics model was built using geostatistical methods. Porosity and water saturation models were built depending on the results of porosity and water saturation values which have been corrected and interpreted in the IP software. Sequential Gaussian Simulation algorithm was used as a statistical method which fits with the amount of the available data. Results and Discussions From porosity and water saturation models for each zone of Asmari reservoir the following conclusions can be shown: The porosity model of the unit Jeribe-Euphrates as shown in figure (9) is characterized by low porosity values in all wells under study but some parts of this unit may show porosity increases to reach 15%. The porosity values in this zone range from (0-15%). From figure (10) of Water saturation model for zone Jeribe-Euphrates shows moderate water saturation values that range from (40-65%), so this zone is represented as having no reservoir unit in the wells under study. The porosity model of upper Kirkuk zone (fig.11) is characterized by high porosity especially in the upper parts of this unit in all well under study. The porosity values in this zone range from (11-30%). Figure (12) of water saturation model in upper Kirkuk zone shows low water saturation in the most parts of this zone. The water saturation values range from (15-40%).The upper kirkuk unit is characterized by high petrophysical properties and good reservoir unit and it contains oil quantities in all wells under study. The petrophysical properties in Buzurgan member change from high in wells FQ-6,FQ-7, and FQ- 20 to low in wells FQ-21 and FQ-15.The figure (13) of porosity model for Buzurgan member shows variation in porosity values from high in wells FQ-6,FQ-7, and FQ-20 but decreases in wells FQ-21 and FQ-15. Porosity values range from (20-25%).Although the Buzurgan member characterized by high porosity in some wells under study but water saturation reaches to high values especially in well FQ-15
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![Figure 1-location map of Fauqi oil field [5].](profile/Buraq-Al-Baldawi/publication/302588732/figure/fig1/AS:360150398455808@1462877955522/location-map-of-Fauqi-oil-field-5_Q320.jpg)
![Figure 2-Structural map of top of Jeribe-Euphrates Fm. modified from [4].](profile/Buraq-Al-Baldawi/publication/302588732/figure/fig2/AS:360150402650112@1462877955546/Structural-map-of-top-of-Jeribe-Euphrates-Fm-modified-from-4_Q320.jpg)
Building a 3D geological model from field and subsurface data is a typical task in geological studies involving natural resource evaluation and hazard assessment. In this paper a 3D geological model for Asmari Reservoir in Fauqi oil field has been built using petrel software. Asmari Reservoir belongs to (Oligocene-Lower Miocene), it represents the...
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... All of these actions are combined into a single data model, which is a three-dimensional grid. This model constitutes a skeleton of the area and will serve as the skeleton upon which all other models will be constructed (Al-Baldawi, 2015;Ibrahim et al., 2022;El Dally et al., 2023). Despite this, there are several faults that have shaped the area. ...
The eastern part of the offshore Nile Delta is one of Egypt's most productive gas provinces. This study utilizes well logs dataset and 2D seismic from Port Fouad marine (PFM) Field to investigate reservoir lithofacies, rock-types as well as the associated gas chimneys, pockmarks, bright anomalies of escaping fluids in the seafloor, and high-faulted zones caused by the chimney's developments. First, structural smoothing and median filters are used to improve the continuity of the stratigraphic horizons while preserving various geological structures, in order to pick all formation tops and structural faults. Afterwards, variance and energy attributes were computed and extracted for amplitude enhancement of various geobodies such as faults, gas chimneys, and bright reflectors. After that, petrophysical analyses revealed that the Upper Miocene Wakar Formation hosts scattered, thin gas pay zones (<10m) with low hydrocarbon saturation values (average Shc = 27.9%), high water saturation (average Sw > 70%), and high shale volume (average Vsh > 30%). These poor reservoir characteristics prevented accumulation of thick gas zones, thereby several gas escape features (e. vertical chimneys) are observed in the region. Finally, the estimated petrophysical parameter logs and the structure maps derived from seismic data are crucial components of the built 3D structural model. This model reveals the presence of four major normal faults (F1, F2, F3, and F4) oriented NW-SE and WNW-ESE, creating grabens and half grabens. These major faults (F1, F2, F3, and F4) are directly related to the inverted tectonics during the Cretaceous-Paleogene compression (Syrian Arc phase). A link between these structural patterns and gas escape zones is proposed, and the absence of good reservoir facies likely promoted an active phase of gas seepage in the study region. In addition, such gas escape chimneys can create catastrophic events on the seafloor and are considered direct evidence for the presence of gas generation and failure in accumulation.
... The method of adding individual continuous properties, such as permeability, porosity, clay volume, and water saturation, to each grid cell is performed by the Petrel program. Petrel hypothesizes that the geological layering inside the mode domain influences the form of the layer that the grid obtains [3]. ...
... Generally, the first stage in creating a 3D geological model is building a 3D grid (Hameed and Saleh, 2022). A 3D geological model can be described by a network consisting of lines in horizontal and vertical directions called a 3D grid (Abaldawi, 2015). A 3D grid that is made up of spaces and boxes. ...
A 3D Geological model was generated using an advanced geostatistical method for the Cretaceous reservoir in the Bai Hassan oil field. In this study, a 3D geological model was built based on data from four wells for the petrophysical property distribution of permeability, porosity, water saturation, and NTG by using Petrel 2021 software. The geological model was divided into a structural model and a property model. The geological structures of the cretaceous reservoir in the Bai Hassan oil field represent elongated anticline folds with two faults, which had been clarified in the 3D Structural model. Thirteen formations represent the Cretaceous reservoir which includes (Shiranish, Mashurah, U.kometan, Kometan Shale, L. Kometan, Gulneni, Dokan, Mauddud, Jawan/Mud, Batiwah, Shuaiba, Garagu, L.Sarmord). According to the property model, the model for each petrophysical property was constructed based on core data and CPI. By using the geostatistical method, the property model was constructed. The Mauddud Formation is considered one of the most promising hydrocarbon reservoirs in the Bai Hassan oil field based on the results of the property model, where the ratio of water saturation is around 30%, the porosity value is reaching up to 31%, and the net to gross ratio is averaging at 70%.
... Making horizons is the process of filling vertical thickness between layers' tops. This vertical thickness must be divided into numbers of sub layers according to reservoir heterogeneity and hydrocarbon content [21]. The number of sub layers of Mishrif reservoir is illustrated in table 3, and this classification according to evaluation of Mishrif reservoir based on CPI logs. ...
The initial oil in place (IOIP) is an important factor that controls economic planning for production and field life. Therefore, this parameter must be determined precisely and carefully. The present paper is dealt with study the impact of adopting two different strategies of property modeling on IOIP value. 3D geological model constructed by using information likewise: contour map, oil formation volume factor, control processing interpretation (CPI) of well logs, and well heads and tops of twelve wells for selected field. The chosen oil field is feeding from Mishrif reservoir and located in southern Iraq. Mishrif reservoir is classified to six layers: MA, MB11, MB12, MB21, MC1, and MC2. Two strategies for distributing petrophysical properties: porosity, water saturation, and net to gross thickness of Mishrif reservoir are utilized. The two strategies are sequential Gaussian simulation and moving average. The volumetric method is used for estimating IOIP values. The impact of using the two strategies of property modeling was very clear where the values of IOIP had a significant difference. The IOIP value of 3D model whose petrophysical properties are distributed using moving average strategy is 5.145 billion barrels, while the 3D model distributed by Gaussian strategy had IOIP equal to 4.195 billion barrels. According to obtained results, the choice of distribution method is very important in estimation of IOIP. Selection of optimal property modeling strategy need to statistical comparison with selected oil field reports and input data, so finally, the closest representation of a protective reservoir and accurate value of IOIP.
... [15]. [21] on his study showed C zone as a part of Upper Kirkuk reservoir with title Buzurgan member, this difference of characterization due to evaluation diversity. ...
Pore pressure is very important parameter that impacting on drilling, production planning and operations. Drilling and production processes cannot be beginning if pore pressure is not estimated. There is a limit of difference between hydrostatic pressure of mud column and pore pressure during drilling to ensure that the layers are preserved from fracturing, as well as that kicking does not occur inside the well. Difference between pore pressure and bottom hole flowing pressure is a key for production process. Over (Abnormal) pressure intervals are causing many problems during drilling. In present study, pore pressure is estimated firstly as a hydrostatic pressure, and secondly, after determination of shale flag, two methods of Eaton slowness and Bowers original are used for detecting of over (Abnormal) pressure shale intervals. Compressional and density logs of three wells (X3, X4, and XD) located at Y oil field and producing from Asmari formation are used to perform the present study. Density log is linearly extrapolated to estimate bulk density from zero depth to last depth point at reservoir. Vertical stress is predicted for these three wells. The vertical stress gradients were 1.03, 0.99, and 0.93 psi/ft for XD, X3, and X4 wells respectively. Results are reveals that Bowers original better than Eaton slowness in detection of over (abnormal) pressure intervals where the last did not cut all shale intervals by compressional slowness shale base line that equal to 80 us/ft so, Eaton slowness method provided either very high over pressure in some shale intervals or subnormal pressure to other shale intervals and that inaccurate while Bowers original method approximately provided all shale intervals as over pressure in reasonable values. Modular dynamic tester measurements for pore pressure of these three wells are used for calibration. Maximum percent error between predicted and measured pore pressure of wells (X3, X4, and XD) are 1.2%, 0.89% and 3% respectively where these percent are very acceptable. Maximum over pressure values in Asmari formation zones at wells are as follows: 6328 psi at depth 3225 m in well X3, 7538 psi at depth 3080 m in well X4, and 6731 psi at true vertical depth 3067 m in well XD.
... Many scholars and oil firms are interested in the Zagros Fold Belt. (Amel et al., 2021;Fouad, 2012;Al-Baldawi, 2020;Al-Saad and Al-Shahwan, 2019;Al-Baldawi, 2015). ...
The current study represents the evaluation of petrophysical characteristics, lithological analysis, and identification of the Asmari Formation for the main and sub-reservoir units in the Abu Ghirab oil field, Maysan, southeast of Iraq. This petrophysical assessment was accomplished using the interpretations of well log data to know the properties of the Asmari Formation reservoir. The available logs such as resistivity, gamma ray, neutron and density logs were converted to digital data using the Diger Sotware. The lithic properties of the reservoir like porosity, total shale saturation, oil and water saturation were interpreted and calculated using the interactive petrophysics software. The lithic and mineral study was completed and the type of mineral filling was known through the cross-plot of the porosity logs for different wells. The petrophysical properties were calculated and represented on the CPI profile. Depending on the petrophysical characteristics, the Asmari Formation was divided into main and sub units, which are: Jeribe-Euphrates and its sub-units A1, A2, and A3; Upper Kirkuk unit and B1, B2, B3, B4 sub-units; and Middle-Lower Kirkuk unit and C subunit. The results showed that the reservoir has economic oil productivity. The subunits B2, B3 in Upper Kirkuk were characterized by high effective porosity values and high hydrocarbon content, and they are the highest produced units in Upper Kirkuk in studied wells. The vary on lithology represents as dolomites in the Jeribe, Euphrates, limestones in the Kirkuk group, and the mineral components were calcite and dolomite.
... The 3D structural modeling comprises; fault modeling, pillar gridding, zonation, and vertical layering. All of these processes were linked in a single data model (Bessa, 2004;Al-Badawi, 2015;Schlumberger, 2010). ...
Al-Baraka is the first explored oil field in the Komombo basin. The formation and evolution of Komombo basin were influenced by tectonic processes from the pre-early Cretaceous period. The main objectives of this study are to; identify hydrocarbon potential in this remote part of Egypt, evaluate and determine the interesting zones within the early cretaceous rocks for hydrocarbon accumulations in Al-Baraka reservoir. Using well logging data, the stratigraphic section and reservoir extent of Al-Baraka field were examined. Three-dimensional geometrical and structural models were also created using seismic reflection data. Al-Baraka reservoir rocks are made up of non-marine sands and shales that were accumulated in a confined marine environment. By the careful interpretation of petrophysical data, different hydrocarbon-bearing zones (R 2 , R 4 , and R 5) can be identified within west Al-Baraka-2 well. These zones were recognized in the Six Hills Formation members E and F of the early Cretaceous. Petrophysical analyses showed that these zones have moderate to good porosity (18.2-20.1%), low shale distribution (8.5-20%), and high average hydrocarbon saturation (42.5%) with high movability. Five zones were recognized based on the interpretation of 3D geometrical modeling. 3D structural modeling shows lateral extension and thickness variation controlled by the effect of faulting. The exploration of hydrocarbon in Komombo basin will contribute to the exploration of more rift basins in southern Egypt.
... All these operations are integrated into a single data model (3D grid). This modeling represents a skeleton of the studied zone from which all other models will be built (Bessa, 2004;Al-Baldawi, 2015;Schlumberger, 2010). ...
The Komombo basin, as well as other rift basins west of the Nile River in Egypt, has not been sufficiently studied from the perspective of petroleum activity. Therefore, an evaluation of the available data on this basin should be performed to provide more valuable information about the hydrocarbon potential there. Early Cretaceous rifting contributes to the maturation of the deeper source rocks within this basin. Moreover, the presence of different structural features (subsidence, uplifts, and normal fault propagation) is a significant factor controlling the movement of the oil and its entrapment within the Al Baraka reservoir. A comprehensive study of seismic reflection and well logging data was applied to investigate the subsurface structural features and identify the promising hydrocarbon-bearing zones in the reservoir. The Six Hills Formation of the Early Cretaceous includes the main reservoir rocks that contribute to the petroleum potential in the area. The objective of this study is to visualize and evaluate the subsurface geological features of the surveyed area that controls petroleum accumulation and trapping. Different maps, cross-sections, 3D geometrical, and 3D structural models were constructed to visualize the subsurface structural configuration and architecture of the reservoir. A calibration process between sonic logs with the velocity of the existing vertical seismic profiling (VSP) data was carried out to produce a more accurate and detailed time–depth relationship at the well location. All results deduced from this study were used to identify and determine the locations of the depocenter and the shoulder of the basin. Also, the results provided a clear and detailed vision of the architecture of the productive hydrocarbon-bearing zones and encourage specialists to look for future hydrocarbon potential in the Komombo basin. Moreover, this study can provide specialists with sufficient information to understand the evolution of rift basins in Komombo and other parts of Egypt.
... Al Baldawi (2015) presented a 3D geological model of Asmari formation by utilizing information of five wells. Porosity and water saturation were distributed by Sequential Gaussian simulation Geostatistical method. ...
... Asmari reservoir is divided into four primary zones (A, B, C, and D), as illustrated in chapter one, based on a number of previous studies, zone A has subzones (A1, A2, and A3), zone B has subzones (B1, B2, B3, and B4), while zone C and D did not have subzone classifications. A zone refers to Jeribe Euphrates, B zone correspond to Upper Kirkuk, C and D belong to Middle-Lower Kirkuk (Taher et al. 2011;Al-Baldawi, 2015). Modern studies merged C and D zones as one zone because they have approximately same rock types and submerged with water. ...
... Al Baldawi (2015) presented a 3D geological model of Asmari formation by utilizing information of five wells. Porosity and water saturation were distributed by Sequential Gaussian simulation Geostatistical method. ...
... Asmari reservoir is divided into four primary zones (A, B, C, and D), as illustrated in chapter one, based on a number of previous studies, zone A has subzones (A1, A2, and A3), zone B has subzones (B1, B2, B3, and B4), while zone C and D did not have subzone classifications. A zone refers to Jeribe Euphrates, B zone correspond to Upper Kirkuk, C and D belong to Middle-Lower Kirkuk (Taher et al. 2011;Al-Baldawi, 2015). Modern studies merged C and D zones as one zone because they have approximately same rock types and submerged with water. ...
