Determination of electrofacies using wireline logs based on multivariate statistical analysis for the Kareem Formation, Gulf of Suez, Egypt

Sharawy, Mohamed S. El; Nabawy, Bassem S.

doi:10.1007/s12665-016-6214-0

Cited by 46 publications

(7 citation statements)

References 28 publications

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“…For the present study, the quality control of the present data is achieved by plotting the bulk density as a function of porosity (Figure a,b). This quality control is required prior to further data processing and modelling (El Sharawy & Nabawy, , ; Kassab et al, ; Nabawy et al, ). This plot indicates a very high reliability of the obtained best fit lines ( R 2 ≥ 0.938) for the ∅ He ‐ρ b plot (Figure a) with less reliability for the ∅ W ‐ρ b relationships ( R 2 ≥ 0.833, Figure b).…”

Section: Discussionmentioning

confidence: 99%

Impacts of microfacies type on reservoir quality and pore fabric anisotropy of the Nubia sandstone in the central Eastern Desert, Egypt

et al. 2019

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The Nubia sandstone has a high potential for water and hydrocarbons exploration in its subsurface extensions. The present work aims to study the Nubia sandstone at Gebel Duwi in the central Eastern Desert to characterize its lithostratigraphic setting, microfacies types, and its petrophysical properties. In addition, impacts of mineral composition and diagenetic history of the Nubia sandstone on its storage and deliverability capacities and on its hydraulic and electric pore fabrics will be estimated. The Nubia sandstone is subdivided into three informal members: a lower trough cross-bedded, coarse-grained with little mud braided fluvial member; a middle planar cross-bedded sandstone with ferruginous siltstone intercalations of meandered fluvial member; and an upper gypsiferous coarsening upward clastic coastal to deltaic sediments. The microfacies analysis indicated that six microfacies are present: quartz arenite, subarkose, arkose, sublitharenite, ferruginous greywacke, and ferruginous siltstone microfacies. Several types of diagenetic processes affected the Nubia sandstone; cementation, compaction, and pressure solution are the main reservoir qualityreducing factors, whereas fracturing, dissolution, and leaching out are the most important reservoir quality-enhancing factors. For the present study, helium and water porosities, air permeability, and electric resistivities (for plugs drilled in three perpendicular directions for each block sample) were measured. Petrophysically, the studied Nubia sandstone can be summed up into three petrophysical facies: Facies-1 (quartz arenite and subarkose), Facies-2 (ferruginous subarkose to greywacke), and Facies-3 (sublitharenite and arkose). The slight ferruginous and clay content of the second facies has slightly increased the grain density values and reduced its storage capacity and deliverability. Porosity (∅ He ) values which are measured by the helium injection for the first and third facies samples are good to excellent (14.6 ≤ ∅ He ≤ 28.9%), whereas their permeability (k) values are good to excellent (106 ≤ k ≤ 2231 md). The second facies is characterized by relatively less petrophysical potential than the other two facies (av. ∅ He = 19.2% and av. k = 557 md). The hydraulic pore anisotropy (λ k ) of the studied three petrophysical facies is isotropic to moderately anisotropic (1.02 ≤ λ k ≤ 1.96), whereas the electric pore anisotropy (λ E ) is less intensive (1.11 ≤ λ E ≤ 1.61).

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Section: Discussionmentioning

confidence: 99%

Impacts of microfacies type on reservoir quality and pore fabric anisotropy of the Nubia sandstone in the central Eastern Desert, Egypt

et al. 2019

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“…Its reservoir quality is graded from good to poor, depending on the sedimentation and geological agents, and subdivided into seven hydraulic flow units (El Sharawy 2013). Also, the Kareem reservoir was divided into six distinctive electrofacies by El Sharawy and Nabawy (2016) which interpreted as mudstone, limestone, dolomite, anhydrite, prospective sandstone, and non-prospective sandstone.…”

Section: Geological Settingsmentioning

confidence: 99%

Integration of mud logging and wire-line logging to detect overpressure zones: a case study of middle Miocene Kareem Formation in Ashrafi oil field, Gulf of Suez, Egypt

Abass

Teama

Kassab

et al. 2019

J Petrol Explor Prod Technol

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The aim of this study is the integration of mud logging and wire-line logging data to detect overpressure zones in Kareem Formation (Middle Miocene), Ashrafi Field, Gulf of Suez, Egypt. The study is performed for the three wells Ash_H_1X_ST2, Ash_I_1X_ST, and Ash_K_1X. The prediction of the abnormal pressure is a quite important factor in the design of the well, where it contributes to avoid many problems during the drilling process and maintain the formation fluids. The abnormal pressure zones occur due to major changes in lithology, petrophysical properties, and fluid type, where these factors lead to differences in pore pressure from hydrostatic pressure, and their prediction is achieved by utilizing rock cuttings, D-exponent, and methane gas; in addition, the porosity and water saturation are estimated from mud logging as real-time data and compared to wire-line logging (resistivity, porosity, and permeability) to determine these zones. The concept of detecting abnormal pressure zones in this study is based on defining the marked changes in the D-exponent trends that arise from the variations of the fluids and the lithology of the Kareem Formation. Therefore, these trends are integrated with the petrophysical parameters such as resistivity, porosity, and permeability from wire-line logging to detect the overpressure zones. So, the overpressure zones are detected in the intercalated sand and shale intervals of the studied wells within the Kareem Formation and are mostly marked by a decrease in the reservoir quality such as permeability, as well as an increase in the resistivity and D-exponent. The thickness of the overpressure zone in Ash_H_1X_ST2 well is influenced by the marl content that reaches up to 80%. The integration results are summarized to determine the average depths of the overpressure zones for the Kareem Formation in the three studied wells. The zone average depths in the Ash_H_1X_ST2 well range from 6022.50 to 6093.30 ft, whereas the zone top is detected in the Ash_I_1X_ST well at the top of the Kareem Formation (6580.00 ft), and the zone bottom at average depth of approximately 6704.20 ft, in addition, the zone average depths in the Ash_K_1X well range from 7718.33 (top) to 7833.33 ft (bottom).

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“…Delineating the reservoir rock properties is necessary to plan water floods including reservoir depositional environment, diagenetic history, structures, interconnectedness of pore spaces, and water/ oil to rock characteristics. Routine core analysis is the most precise tool to understand reservoir characteristics (Ebanks et al 1987;Scheihing et al 2002;El Sharawy and Nabawy 2016a, b;Nabawy and Barakat 2017;Radwan et al 2019a). Incompatibility between reservoir properties, fluids and injected water properties, and the presence of fine solids in water for injection may contribute to formation damage in some reservoirs (Bennion et al 1996(Bennion et al , 1998Moghadasi et al 2002;Yuan and Wood 2018).…”

Section: Introductionmentioning

confidence: 99%

Implementation of Rock Typing on Waterflooding Process During Secondary Recovery in Oil Reservoirs: A Case Study, El Morgan Oil Field, Gulf of Suez, Egypt

et al. 2021

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Waterflooding is one of the most common secondary recovery methods in the oil and gas industry. Globally, this process sometimes suffers a technical failure and inefficiency. Therefore, a better understanding of geology, reservoir characteristics, rock typing and discrimination, hydraulic flow units, and production data is essential to analyze reasons and mechanisms of water injection failure in the injection wells. Water injection failure was reported in the Middle Miocene Hammam Faraun reservoir at El Morgan oil field in the Gulf of Suez, where two wells have been selected as injector’s wells. In the first well (A1), the efficiency of injection was not good, whereas in the other analog A2 well good efficiency was assigned. Therefore, it is required to assess the injection loss in the low efficiency well, where all aspects of the geological, reservoir and production data of the studied wells were integrated to get a complete vision for the reasons of injection failure. The available data include core analysis data (vertical and horizontal permeabilities, helium porosity, bulk density, and water and oil saturations), petrographical studies injection and reservoir water chemistry, reservoir geology, production, and injection history. The quality of the data was examined and a set of reliable X–Y plots between the available data were introduced and the reservoir quality in both wells was estimated using reservoir quality index, normalized porosity index, and flow zone indicator. Integration and processing of the core and reservoir engineering data indicate that heterogeneity of the studied sequence was the main reason for the waterflooding inefficiency at the El Morgan A1 well. The best reservoir quality was assigned to the topmost part of the reservoir, which caused disturbance of the flow regime of reservoir fluids. Therefore, it is clearly indicated that rock typing and inadequate injection perforation strategy that has not been aligned with accurate hydraulic flow units are the key control parameters in the waterflooding efficiency.

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Determination of electrofacies using wireline logs based on multivariate statistical analysis for the Kareem Formation, Gulf of Suez, Egypt

Cited by 46 publications

References 28 publications

Impacts of microfacies type on reservoir quality and pore fabric anisotropy of the Nubia sandstone in the central Eastern Desert, Egypt

Impacts of microfacies type on reservoir quality and pore fabric anisotropy of the Nubia sandstone in the central Eastern Desert, Egypt

Integration of mud logging and wire-line logging to detect overpressure zones: a case study of middle Miocene Kareem Formation in Ashrafi oil field, Gulf of Suez, Egypt

Implementation of Rock Typing on Waterflooding Process During Secondary Recovery in Oil Reservoirs: A Case Study, El Morgan Oil Field, Gulf of Suez, Egypt

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