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Collaborating Authors
Illizi Province
In this study, we interpreted a cumulative 600m acoustic image log across the Triassic to Cambro-Ordovician interval in the Berkaoui oil field, Algeria. We interpreted 40 distinct breakout zones which have a combined length of 210m. These breakouts are aligned in the NNE-SSW direction indicating a mean maximum horizontal stress (SHmax) azimuth of 110ยฐN. The observed breakouts are ranked as ยA-Qualityย following the World Stress Map ranking guidelines. The angular width of each breakout has been inferred from the image log analysis and the same has been utilized to infer the SHmax gradient by stress polygon approach following the frictional faulting mechanism. The stress polygon across all the breakout intervals provides a practical Shmax range between 24.7-31.1 MPa/km, with an average gradient of ~ 27 MPa/km. Considering the Shmin range across the studied intervals, we infer a SHmax/Shmin ratio dominantly between 1.40-1.65, which is a much narrower and better-constrained range when compared to the previously published ranges from nearby fields with the same stratigraphy. The relative magnitudes of the in-situ stresses indicate a strike-slip faulting regime in the Berkaoui field. This study presents the utility of image log analysis and integration of breakout interpretation to obtain a more robust geomechanical model with reduced SHmax uncertainty.
- North America > United States (1.00)
- Asia (1.00)
- Africa > Middle East > Algeria > Illizi Province (0.28)
- Africa > Middle East > Algeria > Ouargla Province > Hassi Messaoud (0.28)
- Phanerozoic > Paleozoic > Ordovician (1.00)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.75)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.47)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.46)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.72)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.99)
- Africa > Middle East > Egypt > Western Desert > Greater Western Dester Basin > Abu Gharadig Basin > Abu Gharadig Field (0.99)
- (10 more...)
CONSTRAINING MAXIMUM HORIZONTAL STRESS USING WELLBORE BREAKOUTS -- A CASE STUDY FROM ORDOVICIAN TIGHT RESERVOIR OF NORTHEASTERN OUED MYA BASIN, ALGERIA
Baouche, Rafik (University MHamed Bougara Boumerdes) | Sen, Souvik (Baker Hughes) | Ganguli, Shib Sankar (CSIR-National Geophysical Research Institute) | Benmamar, Salim (Baker Hughes) | Kumar, Prakash (CSIR-National Geophysical Research Institute)
In this study, we interpret the maximum horizontal stress (SHmax) azimuth from the breakout positions of wellbore and attempt to constrain the SHmax gradient based on the interpreted breakout width. A cumulative of 110 m of breakouts were deciphered within the Ordovician Hamra Quartzite interval of the Oued Mya Basin from a 138 m of acoustic image log. These breakouts were ranked as A-Quality following the World Stress Map ranking guidelines. We infer a mean SHmax orientation of N28E 8. Following the frictional faulting mechanism and stress polygon approach, measurement of minimum horizontal stress (Shmin) from minifrac tests and observations of compressive failures from acoustic image log provided strong constraints on the SHmax magnitude in the reservoir interval in the absence of core-measured rock strength. Interpreted breakout widths exhibit a range between 32.6 and 90.81, which indicated a SHmax range of 24.434.7MPa/km. The average breakout width of 62.58 translates to a narrower SHmax gradient range, varying between 27.2 and 31.2 MPa/km. The relative magnitudes of the principal stresses indicate a strong strike-slip tectonic stress state. Considering all the uncertainties, we infer a SHmax/Shmin ratio of 1.411.81 within the Ordovician interval.
- Africa > Middle East > Algeria > Eastern Algeria (0.71)
- Africa > Middle East > Algeria > Ouargla Province > Hassi Messaoud (0.28)
- Phanerozoic > Paleozoic > Ordovician (0.92)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.53)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.34)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.70)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.99)
- Africa > Middle East > Tunisia > Kebili Governorate > Chotts Basin > Hamra Quartzite Formation (0.99)
- (11 more...)
New Hybrid MCDM Approach for an Optimal Selection of Maintenance Strategies: Results of a Case Study
Khanfri, N. E. H. (LRPI Laboratory, Institute of Health and Safety, University of Batna 02 (Corresponding author)) | Ouazraoui, N. (LRPI Laboratory, Institute of Health and Safety, University of Batna 02) | Simohammed, A. (LRPI Laboratory, Institute of Health and Safety, University of Batna 02) | Sellami, I. (Department of Applied Engineering, Kasdi Merbah University-Ouargla)
Summary Industrial systems are becoming more sophisticated, and their failure can result in significant losses for the company in terms of production loss, maintenance costs, fines, image loss, etc. Conventional approaches to modeling and evaluating the failure mechanisms of these systems do not consider certain important aspects, such as the interdependencies between failure modes (FMs) with information and data containing uncertainties as they are generally collected from expertsโ judgments. These restrictions may lead to improper decision-making. The use of more advanced techniques to model and assess the interdependencies among componentsโ failures under uncertainties seems to be more than necessary to overcome these deficiencies. It is in this context that the proposed approach fits. It consists of proposing a hybrid multicriteria decision-aking (MCDM) approach that combines several techniques for a better selection of maintenance strategies. Using the failure mode and effects analysis (FMEA) technique, the potential FMs of components, along with their causes and effects, are identified. The relative importance (or weight) of these FMs is determined using the fuzzy simple additive weighing (FSAW) method based on how they affect the systemโs goals. The causal relationships between FMs and their final weights are determined by the fuzzy cognitive maps (FCM) method and the nonlinear Hebbian learning and differential evolution (NHL-DE) algorithm. Finally, based on the final FM weights provided by the FCM, the simple additive weighing (SAW) method is used to select the optimal maintenance strategies. The results of applying the proposed approach to an operating compressor lubrication and sealing oil system demonstrate its importance and usefulness in assisting system operators to efficiently allocate the optimal maintenance strategies, considering the strong correlation between FMs and their effects on system performance while accounting for the uncertainties associated with expertsโ judgments. These correlation effects have led to changes in the assigned weights of the selected FMs. Specifically, the FM related to the low output of the lube/seal oil pump, which was initially assigned a lower priority, and with the correlation effects has become the first critical FM. This shift in prioritization emphasizes the need to address this particular FM promptly. By focusing on addressing these high-priority FMs, maintenance efforts can be optimized to prevent or mitigate more severe consequences. Among the various maintenance strategies evaluated, it was determined that the combination of condition-based maintenance (CBM) and precision maintenance (PrM) yields the most favorable outcome in terms of mitigating the impact of accidental failures and undesired events on the selected system.
- North America > United States (0.93)
- Asia > Middle East (0.92)
- Africa > Middle East > Algeria (0.67)
- Europe (0.67)
Integration of 1-D Geomechanical Model for Minimum Horizontal Stress Estimation and Validation with Micro-frac Tests โ Case Study from Touggourt Field, Algeria
Podder, Tuhin (Baker Hughes) | Chakrabarti, Prajit (Baker Hughes) | Sen, Souvik (Baker Hughes) | Ouriri, Feriel (Sonatrach) | Aichour, Imad (Sonatrach) | Hammoudi, Abdelmalek (Sonatrach) | Bouarfetine, Djilali (Sonatrach) | Perumalla, Satya (Baker Hughes)
Abstract This study presents comprehensive geomechanical modeling of the tight Triassic reservoirs from the Touggourt field, eastern Algeria. The primary objective was to constrain minimum horizontal stress in the T1 and T2 reservoirs by microfrac testing. Wireline logs, direct pore pressure measurements, acoustic and resistivity image logs were integrated for geomechanical modeling. A strike-slip tectonic stress regime with NW-SE SHmax orientation was inferred. A pre-job geomechanical model was prepared for selecting optimum intervals for microfrac testing. Contrast in horizontal stress magnitudes, density-porosity, and rock-mechanical properties, expected breakdown pressure being within tool limit, and in-gauge caliper response have been considered for choosing the microfrac test intervals, while honoring the operatorโs geological objectives. Based on the microfrac test data, we inferred a 0.88-0.94 psi/ft Shmin gradient with 1.04-1.08 psi/ft breakdown pressure gradient within these Triassic reservoirs. Integrated geomechanical approach in the pre-planning as well as real-time advisory facilitated successful formation break down in a very tight and strong lithofacies. High quality data acquired during microfrac operation yielded confident fracture closure interpretation and post-job geomechanical model calibration, which has critical implications in future drilling and completion optimization.
- Phanerozoic > Mesozoic > Triassic (0.61)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.47)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.47)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.35)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.99)
- Africa > Middle East > Egypt > Western Desert > Greater Western Dester Basin > Abu Gharadig Basin > Abu Gharadig Field (0.99)
- (11 more...)
Characterization of Maximum Horizontal Stress from Wellbore Failures โ A Case Study from the Tight Paleozoic Hamra Quartzite Oil Reservoir of Oued Mya Basin, Algeria
Baouche, Rafik (University MโHamed Bougara Boumerdes) | Sen, Souvik (Baker Hughes) | Benmamar, Salim (Baker Hughes) | Perumalla, Satya (Baker Hughes)
Abstract The Cambro-Ordovician Hamra Quartzite Formation is one of the important reservoirs from Algerian Sahara. The objectives of this study were to characterize the wellbore breakouts and constrain the maximum horizontal stress (Shmax) based on the inferred compressive failures within the Paleozoic reservoir. A-Quality breakouts were deciphered within the reservoir interval from a cumulative of 138m of acoustic image log indicating a mean SHmax orientation of N118หEยฑ8ห. Interpreted breakout widths exhibit a range between 32.6ห and 90.81ห, which indicated a SHmax range of 24.4-34.7 MPa/km. The average breakout width of 62.58ห translates to a SHmax gradient range of 27.2 and 31.2 MPa/km. The relative magnitudes of the principal stresses indicate a strong strike-slip tectonic stress state with a SHmax/Shmin ratio of 1.41-1.81 within the Ordovician interval. Following the frictional faulting-based stress polygon approach, measurement of minimum horizontal stress (Shmin) from minifrac tests and observations of compressive failures from acoustic image log provided strong constraints on the SHmax magnitude in the studied Ordovician tight reservoir interval in the absence of core-measured rock strength.
- Africa > Middle East > Algeria > Eastern Algeria (0.53)
- Africa > Middle East > Algeria > Ouargla Province > Hassi Messaoud (0.29)
- Phanerozoic > Paleozoic > Ordovician (1.00)
- Phanerozoic > Paleozoic > Cambrian (0.67)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.47)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Metamorphic Rock > Quartzite (0.65)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.51)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.99)
- Africa > Middle East > Tunisia > Kebili Governorate > Chotts Basin > Hamra Quartzite Formation (0.99)
- (11 more...)
Abstract The main objective of this study is to provide a reservoir model that can guide geologists and geophysicists working on tight gas reservoirs in Algeria towards achieving selective drilling, ensuring both reservoir productivity and cost-effectiveness. The proposed approach aims to construct a more accurate non-conventional reservoir model for a fully controlled field, based on the extraction of tortuosity as a function of seismic and logging data. This enables the generation of a pore geometry model, initially near the wells and subsequently at the reservoir scale. Moreover, several deterministic seismic attributes have been derived from the seismic cube. The proposed equations linking the Petrophysical parameters have been mathematically demonstrated and tested. The results obtained are highly promising for unconventional shale gas reservoirs. The application of this novel technique in characterizing unconventional reservoirs facilitates the precise identification of potential net pay zones with great accuracy, optimizing exploration efforts and daily upstream production in mature reservoirs. It also aids in the strategic placement of new wells, determining their density and configurations. Furthermore, it offers a more precise and comprehensive reservoir characterization, improved reservoir geometry mapping, and a significant reduction in dry wells, thereby optimizing costs. Consequently, this developed model contributes to generating economic benefits by enhancing secondary recovery in mature fields, extending reservoir exploitation life by minimizing exploration uncertainties in gas reservoirs.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.30)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (0.35)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (0.88)
Characteristics and controlling factors of petroliferous reservoirs in the Permian Lower Urho Formation, western Mahu Slope, Junggar Basin, Northwest China
Fang, Zhibin (Xinjiang Oilfield Company) | Hao, Weiguo (Xinjiang Oilfield Company) | Nuertai, Maidina (Xinjiang Oilfield Company) | Zhang, Fanggui (Xinjiang Oilfield Company) | Mao, Beibei (Xinjiang Oilfield Company) | He, Naixiang (Xinjiang Taiqi Petroleum Technology Co., Ltd.)
Abstract Numerous hydrocarbon discoveries in the lower Urho Formation of the western Mahu Slope, China indicate that potential petroliferous reservoirs may exist in that region. However, issues concerning the reservoir characteristics and associated controlling factors remain unclear. To determine the characteristics and associated controlling factors of these reservoirs, we conducted integrated analysis of the 3D seismic volume, wireline logs, mud logs, cores, thin sections, porosity, and permeability data. Several lithologic types were identified from the core, casting thin section, and mud-log data (including mudstone, sandstone, gravity flow-derived glutenite, transitional glutenite, and traction flow-derived glutenite). The contact relationship was determined from the casting thin section data, and it included point contact and lineal contact, followed by concavo-convex contact and suture contact. We found the dominant pore types were found to be intergranular pores, followed by intragranular pores, intramatrix pores, and cracks. The porosity and permeability data reveal that sandstone and traction flow-derived glutenite commonly form low-porosity and low-permeability reservoirs, whereas transitional glutenite commonly forms low-porosity and ultralow-permeability reservoirs and gravity flow-derived glutenite generally forms low-porosity and ultralow-permeability reservoirs. This integrated analysis finds that tectonic movements and a sedimentary environment control the physical properties of the reservoirs. The tectonic movements control reservoir characteristics through thrust fault systems and large-scale provenance, and the sedimentary environment controls reservoir characteristics via facies distribution and lacustrine fluctuation. The insights gained from this study can provide knowledge about the characteristics and associated controlling factors of the reservoirs in the Permian Lower Urho Formation within the western Junggar Basin. These insights can also benefit petroleum reserve and hydrocarbon production exploration in the study area and further petroleum exploration in other areas with similar sedimentary/tectonic settings.
- Geology > Structural Geology > Tectonics (1.00)
- Geology > Sedimentary Geology > Depositional Environment (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.75)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.68)
- Europe > Netherlands > German Basin (0.99)
- Europe > Germany > German Basin (0.99)
- Europe > Denmark > German Basin (0.99)
- (36 more...)
Fracture Roughness Characterization from 360 Unrolled Core Images in a Sandstone Reservoir, Case Study, Algeria, Hassi Messaoud
Ifrene, Ghoulem E. H. (University of North Dakota) | Irofti, Doina (University of North Dakota) | Khouissat, Abdelhakim (University of North Dakota) | Pothana, Prasad (University of North Dakota) | Aihar, Aimene (University of North Dakota) | Li, Bo (Tongji University)
ABSTRACT Various existing indirect measurement methods and techniques in the petroleum industry are used to estimate some of the fracture parameters, such as sonic and electrical image logs. However, none of them can estimate the fracture roughness and the degree of mismatch between the two opposite fracture sides due to the sampling resolution. These two are important parameters to consider when dealing with geomechanics and fluid flow in tight naturally fractured reservoirs because they are important in quantifying shear strength and permeability. A quantification and detailed characterization of the joint roughness coefficient (JRC) and the degree of mismatch has been done on fractures gathered in a total of 23 wells in the Algerian Cambro -Ordovician oil-bearing formation Hassi Messaoud which consists of sandstone, clay, and some volcanic intrusions. These data have been collected from the digitalization of high-resolution unrolled 360-core photographs at the reservoir level. The results have been correlated with rock type, grain size, and fracture dip angle. Fracture roughness is ranging between 5 (low) to 19 (high) on the JRC scale and can be predicted from analysis of the general reservoir rock types (sandstone, eruptive, and clay). The results are applicable to other, especially siliciclastic reservoir lithologies, and will therefore contribute to defining a more accurate aperture and permeability estimation in building reliable Discrete Fracture Network (DFN) models. INTRODUCTION Fracture roughness is a key parameter in characterizing the permeability and fluid flow in petroleum (Camac et al., 2006) and geothermal systems (Porlles & Jabbari, 2022). As the majority of currently used large-scale models still significantly rely on simplified smooth parallel-plate models and its related models for naturally fractured reservoirs with rough walls, it is crucial to quantify the roughness in order to enhance the performance of these models (Bodin et al., 2007).
- Africa > Middle East > Algeria > Ouargla Province > Hassi Messaoud > Oued Mya Basin > Hassi Messaoud Field (0.99)
- Africa > Middle East > Algeria > Ouargla Province > Hassi Messaoud > Berkine Basin (Trias/Ghadames Basin) > Hassi Messaoud Field (0.99)
- Africa > Middle East > Algeria > Illizi Province > Illizi Basin (0.94)
- (3 more...)
Formation Sampling Optimization Using Borehole Images and Acoustic Data in Tight Gas Sand Reservoir
Hamadas, Manel (Petroleum Engineering and Development Sonatrach) | Sokhal, Abdallah (Petroleum Engineering and Development Sonatrach) | Bazine, Badreddine (University of Constantine 2 Abdelhamid Mehri)
ABSTRACT In this paper, we present an integrated workflow designed to characterize the natural fracture systems and to optimize fluid sampling in a very complex and heterogeneous fractured tight sandstone reservoir. Conventional techniques are not suited for tight formations, and to overcome this challenge it is imperative to implement and enhance new technology. This advanced workflow aims to decrease uncertainties at different stages of the reservoir lifecycle through combined advanced tools. Electrical and Acoustic borehole images, Full Acoustic Waveform, and MDT Dual packer were incorporated in this study to optimize fluid sampling and increase the success rate of economic recovery. INTRODUCTION Almost all hydrocarbon reservoirs are affected in some way by natural fractures, but the effects of fractures are often poorly understood and largely underestimated. In tight reservoirs, natural fractures created through complex tectonic activity help create secondary porosity and promote communication between reservoir compartments (Irofti et al., 2022). However, these highly permeable channels sometimes short-circuit fluid flow in the reservoir, causing premature production of water or gas and rendering secondary recovery initiatives ineffective (Bratton et al., 2006).Since the introduction of the wireline formation testers in 1955, these tools have provided the oil and gas industry with measurements for the determination of formation pressure, fluids in-situ as well as giving formation fluid samples for identification and analysis. This conventional technique is well suited for thick and permeable clastic formations. Under low porosity and low permeability conditions, the wireline formations testers become unsuitable as they may not be able to isolate the zone, may miss a thin zone or in a formation with very low permeability, the contact area with the packer may be too small to let the fluid flow. When testing is to be conducted out employing pricey rig operations, evaluation of heterogeneous reservoirs using open hole logs and cores carries some risk (Aoun, Soto, et al., 2022; Ifrene et al., 2023) The modest success rate of sampling operations, fluid sampling presents a challenge in tight reservoirs, therefore it is imperative to adopt innovative techniques. To overcome this challenge, we proposed in this article a workflow to increase and optimize the success rate. This includes the combination of borehole image logs and acoustic waveforms, two technologies aiming to enhance formation sampling and recovery rate.
- Phanerozoic > Paleozoic > Ordovician (0.51)
- Phanerozoic > Paleozoic > Cambrian (0.47)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- North America > United States > South Dakota > Williston Basin (0.99)
- North America > United States > North Dakota > Williston Basin (0.99)
- North America > United States > Montana > Williston Basin (0.99)
- (7 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Borehole imaging and wellbore seismic (1.00)
- Information Technology > Artificial Intelligence > Machine Learning (0.46)
- Information Technology > Software (0.34)
Characterization of a Tight Gas Reservoir Using the Integration of Electrofacies and Fracture Aperture, Ahnet, Algeria
Irofti, Doina (University of North Dakota) | Ifrene, Ghoulem E. H. (University of North Dakota) | Aihar, Aimene (University of North Dakota) | Bouabdallah, Nassim (University of North Dakota) | Khouissat, Abdelhakim (University of North Dakota) | Djemai, Safouane (University of Sciences and Technology Houari Boumediene)
ABSTRACT The integration of this heterogeneity analysis with the interpreted fractures of the four wells in the area shows that the lithology has a major influence on the number and type of fractures. The well logs that are most impacted by composition were used to perform cluster analysis in four wells. Cluster analysis generates more representative scaled input parameters for reservoir characterization, which may be compared to the fractures obtained from borehole imaging result. On the basis of their measurable features, these approaches group like things and identify them from dissimilar objects. Because the procedure is neither driven by an external model or specified by a reference training set of previously known items, this clustering is known as unsupervised classification. We employed cluster analysis to classify rocks based on their core compositional characteristics. We utilized well logs that were impacted by composition in this investigation (NPOR, RHOB, GR and PEF). The cluster analysis was carried out using the Techlog software module Heterogeneous Rock Analysis (HRA). INTRODUCTION Serra & Abbott, 1980 coined the word "electro facies," which they define as "the set of log responses that distinguishes a bed and allows it to be recognized from others" (Kumar et al.,2006). Because log responses are measures of the physical qualities of rocks, electro facies may typically be ascribed to one or more lithofacies. Petroleum prospecting and reservoir characterization require the identification of facies. Facies were previously determined manually using graphical approaches such as cross-plotting from wire-line recordings and linking their behavior to cores. Several mathematical methods have recently been devised to automate the job of identifying facies. The quality of the distribution of petrophysical characteristics is driven by reservoir rock type, which is critical for reservoir characterization (Cherana et al., 2022; Doghmane et al., 2022). It improves knowledge of fluid flow, rock storage capacity, and pore size distribution. Many different criteria may be used to classify rock types. Rock typing divides reservoir rocks into discrete units that were formed under comparable geological settings and have undergone similar diagenetic changes (Guo et al., 2005). Fracture aperture characteristics in a reservoir rock are the crucial parameters that control the quality of tight reservoir rock (Mahmood & Guo, 2019) and need to be considered in reservoir rock typing. This research combines rock classification with knowledge of fracture parameters such as aperture.
- North America > United States (1.00)
- Africa > Middle East > Algeria (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.30)
- Africa > Middle East > Algeria > Illizi Province > Illizi Basin (0.99)
- Africa > Middle East > Algeria > Central Algeria > Ahnet-Timimoun Basin (0.99)
- North America > United States > Arkansas > Magazine Field (0.89)
- Europe > United Kingdom > England > London Basin (0.89)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)