Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
fracture height
Fracture Morphology Evaluation of Surrogate Model for Fast Prediction Using Machine Learning
Hu, Zhongyu (China University of Petroleum-Beijing) | Sheng, Mao (China University of Petroleum-Beijing) | Wei, Zhaoyang (China University of Petroleum-Beijing) | Tian, Shouceng (China University of Petroleum-Beijing) | Zhou, Jun (Sinopec Petroleum Engineering Technology Research Institute Co. Ltd.) | Hu, Shimeng (China University of Petroleum-Beijing)
Abstract Fracture morphology is the fundamental data to optimize hydraulic fracturing design. However, the physical modeling and simulation is time consuming involving data preparation, model parameter setting and validation, time-consuming running. Machine Learning (ML) methods have the potential to integrate multi-source data and enhance calculation efficiency, thus enable to be critically useful in fracture morphology prediction. This paper aims to create a ML-based surrogate model for quick fracture morphology prediction. The approach involves the numerical simulation of hydraulic fracturing in two blocks wells, the combination of geological and engineering parameters to be a dataset. Particularly, the pumping time-series data were integrated by encoding and the Conditional Generative Adversarial Networks were used to expand the samples in order to enhance the model's capabilities. Following this, the correlation and principal component analyses were used for the feature engineering to identify key factors for stimulation effectiveness and surrogate model inputs. The comparative analysis demonstrated the excellent predictive ability of the fused Recurrent Neural Network and Multi-Layer Perceptron model, reducing validation set errors by approximately 15%. This work demonstrates the feasibility of ML-based surrogate models for predicting fracture morphology, with the advantages of fast, efficient and integrated multi-source data.
- Asia > China (0.48)
- Asia > Middle East > Saudi Arabia (0.28)
- Geology > Geological Subdiscipline > Geomechanics (0.95)
- Geology > Rock Type > Sedimentary Rock (0.70)
- North America > United States (0.89)
- North America > Canada (0.89)
- Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning (1.00)
- Information Technology > Artificial Intelligence > Machine Learning > Neural Networks > Perceptrons (0.68)
- Information Technology > Artificial Intelligence > Machine Learning > Neural Networks > Deep Learning (0.68)
Quantitative Hydraulic-Fracture-Geometry Characterization with Low-Frequency Distributed-Acoustic-Sensing Strain Data: Fracture-Height Sensitivity and Field Applications
Liu, Yongzan (Texas A&M University) | Jin, Ge (Colorado School of Mines) | Wu, Kan (Texas A&M University (Corresponding author)) | Moridis, George (Texas A&M University and Lawrence Berkeley National Laboratory)
Summary Low-frequency distributed acoustic sensing (LF-DAS) has been used for hydraulic fracture monitoring and characterization. Large amounts of DAS data have been acquired across different formations. The low-frequency components of DAS data are highly sensitive to mechanical strain changes. Forward geomechanical modeling has been the focus of current research efforts to better understand LF-DAS signals. Moreover, LF-DAS provides the opportunity to quantify fracture geometry. Recently, Liu et al. (2021a, 2021b) proposed an inversion algorithm to estimate hydraulic-fracture width using LF-DAS data measured during multifracture propagation. The LF-DAS strain data are linked to the fracture widths through a forward model developed based on the displacement discontinuity method. In this study, we first investigated the impacts of fracture height on the inversion results through a numerical case with a four-cluster completion design. Then we discussed how to estimate the fracture height based on the inversion results. Finally, we applied the inversion algorithm to two field examples. The inverted widths are not sensitive to the fracture height. In the synthetic case, the maximum relative error is less than 10% even when the fracture height is two times the true value. After obtaining the fracture width, the fracture height can be estimated by matching the true strain data under various heights with a strong smooth weight. The error between the calculated strain and true strain decreases as the height approaches the true value. In the two field examples, the temporal evolutions of the width summation of all fractures and the width of each fracture show consistent behaviors with the field LF-DAS measurements. The calculated strain data from the forward model match well with the field LF-DAS strain data. The results demonstrate the robustness and accuracy of the proposed inversion algorithm.
A Novel Environmentally Friendly, Cost Effective Method for Hydraulic Fracture Geometry Evaluation: Cased Hole Cross-Dipole Data
Al Isaee, Omar Mohammed (Petroleum Development Oman) | Smirnov, Dmitrii (Petroleum Development Oman) | Al Hadhrami, Abdullah (Petroleum Development Oman) | Mahrooqi, Alkhattab (Petroleum Development Oman) | Shabibi, Hilal (Petroleum Development Oman) | Sayapov, Ernest (Petroleum Development Oman) | Moiseenkov, Alexey (Petroleum Development Oman) | Kaabi, Saqer (Petroleum Development Oman)
Abstract Cased hole cross-dipole acoustic acquisition is a novel environmentally friendly and cost-effective method for hydraulic fracture geometry evaluation. This method eliminates the environment contamination by the radioactive tracers and replaces the costly micro-seismic monitoring system. Radioactive tracer usage has a risk of pollution associated with improper storage, transportation and use of low dose, short half-life radioactive materials. The new technology eliminates the risk of having radioactive contamination during hydraulic fracturing operations. The sonic anisotropy measurements comparison taken before and after the hydraulic fracturing job allows estimating differential acoustic anisotropy and enables hydraulic fracture geometry evaluation. The method replaces radioactive (R/A) tracers and eliminates any risk of radioactive contamination, high cost, and complex hydraulic fracturing microseismic monitoring (HFM) operation which requires well monitoring. The method was successfully implemented in Greater Birba Cluster in the Sultanate of Oman, during hydraulic fracturing operations in 2020. Results were compared and validated with radioactive tracers, spectral noise log and microseismic monitoring data. This was a first use of sonic anisotropy measurements for fracture geometry evaluation in Petroleum Development Oman (PDO) and the Gulf Cooperation Council (GCC) region. In terms of Zero radiation Risk: The common R/A Tracers Antymoniy-124, Iridium-192 and Scandium-46 have a half-life from 60 to 83 days. One curie of these tracers will give a dose rate of 480 -1090 mR per hour at a meter. Tracers are compounds with both internal and external exposure hazards to humans; they emit highly energetic gamma/beta radiation which can cause localized damage if ingested, inhaled or absorbed by the skin. Externally, both beta and gamma radiation can cause localized damage to exposed areas. Eliminating operations with these materials reduces risk of exposure hazard for field personnel to zero.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.47)
Influence of Natural Fractures on Multi-Stage Hydraulic Fracture Propagation in Tight Middle Eastern Reservoir
Al Mteiri, Shaikhah Abdulla (ADNOC Offshore) | Suboyin, Abhijith (Khalifa University of Science and Technology) | Rahman, Md Motiur (Khalifa University of Science and Technology) | Haroun, Mohammed (Khalifa University of Science and Technology)
Abstract This extensive study deals with propagation behavior of induced hydraulic fractures in naturally fractured formation within heterogeneous Middle Eastern tight gas reservoirs. This can strongly support the development and design process of highly heterogeneous reservoirs in the Middle East. This comprehensive investigation based on field data demonstrates the assessment methods of hydraulic fracture propagation behavior and its correlated effects in presence of natural fractures. A sensitivity analysis showing the significance of hydraulic fracturing treatment design that are operationally controllable is also presented. Further assessment in terms of varying fracture geometry, natural fracture sets and its effect on the productivity are also presented. The introduced natural fracture sets further illustrate the significance of the natural fracture properties in this assessment. An intensive parametric study would additionally assist to understand the underlying flow behavior in the presence of complex fracture sets in tight reservoirs. Stress contrast, fracture toughness, orientation and angle of intersection are a few critical factors that can be coupled for further analysis. The results have been extended to current field applications while incorporating a case study field data of a recently operated fracturing job within the Middle East. Moreover, a parametric workflow that suggests optimum design parameters including number of transverse hydraulic fractures/clusters, their orientation and spacing, and parameters of fracturing materials, are also proposed. A comprehensive investigation was conducted to create a representative model for a Middle Eastern tight gas formation with provided field data. This study is unique as it is based on a Middle Eastern candidate field and offers an insights to challenges and assist future fracturing designs for the region.
- North America > United States (1.00)
- Asia > Middle East > UAE (0.70)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.94)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.31)
- Asia > Middle East > UAE > Rub' al Khali Basin (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Abu Dhabi Field (0.97)
Conventional Tight Gas Field Through Unconventional Eyes: Data Analytics Help to Optimize Fracture Design and Operations
Yuan, Roger (Petroleum Development Oman) | Bahri, Khalfan (Petroleum Development Oman) | Veeken, Cornelis (Petroleum Development Oman) | Shoaibi, Sultan (Petroleum Development Oman)
Abstract Deep tight gas fields in Northern Oman are often compared to and approached with unconventionals due to their tight matrix properties and the necessity of employing hydraulic fracturing to deliver productivity. Complicated by operational constraints and field histories, hydraulic fracture effectiveness – how fracture stimulation delivers relative to how much matrix flow contributes to production – remains a puzzle and a challenge. This further affects how to optimize existing completion and stimulation strategy in order to improve the value proposition. In this study, we review the fracture and production performance of a mature gas field in Northern Oman. Integrating data of various technical disciplines, we re-examine a wealth of cumulative field data over two decades of operations with an aim to identify the key enablers for fracture placement and production. With integration of reservoir properties, geomechanics, and time-lapse production profiles, we identify that geomechanics plays a key role in controlling reservoir fraccability and the placement of hydraulic fractures. While hydraulic fracture containment within the Barik formation has been well recognized and considered a given in multi-staged fractured vertical wells, the creation of fracture heights is found dependent on the in-situ stress conditions and pumping metrics, which further links to productivity. Such inter-relationship could potentially be utilized to optimize fracture performance by a refined placement strategy. With big data, the common technical opinions that normally arise from a deterministic approach on limited data can be better visualized and addressed. The statistical strength of the analysis leads to improved understanding of the subsurface complexity, interaction of reservoir quality with completion design, and a suite of future optimization opportunities.
- Asia > Middle East > Oman > Central Oman > South Oman Salt Basin > Mahwi Formation (0.99)
- Asia > Middle East > Oman > Central Oman > Barik Formation (0.99)
- Asia > Middle East > Oman > Miqrat Formation (0.98)
- Asia > Middle East > Oman > Al Wusta Governorate > Arabian Basin > Rub' al-Khali Basin > Barik Field > Barik Formation (0.98)
Numerical Study on Proppant Transport in Hydraulic Fractures Using a Pseudo-3D Model for Multilayered Reservoirs
Zhang, Xi (China University of Geosciences (Corresponding author)) | Yang, Lifeng (Research Institute of Petroleum Exploration and Development, CNPC) | Weng, Dingwei (Research Institute of Petroleum Exploration and Development, CNPC) | Wang, Zhen (Research Institute of Petroleum Exploration and Development, CNPC) | Jeffrey, Robert G. (SCT Operations Pty Ltd.)
Summary In this paper, we incorporated a kinematic proppant transport model for spherical suspensions in hydraulic fractures developed by Dontsov and Peirce (2014) in a pseudo-3D hydraulic-fracture simulator for multilayered rocks to capture a different proppant transport speed than fluid flow and abridged fracture channel by highly concentrated suspensions. For pressure-driven proppant transport, the bridges made of compact proppant particles can lead to both proppant distribution discontinuity and increased fracture aperture and height because of the higher pressure. The model is applied to growth of a fracture from a vertical well, which can contain thin-bedded intervals and more than one opened hydraulic-fracture interval, because the fracture plane extends in height through layers with contrasts in stress and material properties. Three numerical examples demonstrate that a loss of vertical connectivity can occur among multiple fracture sections, and proppant particles are transported along the more compliant layers. The proppant migration within a narrow fracture in a thin soft rock layer can result in bridging and formation of a proppant plug that strongly limits fluid speed. This generates an increase of injection pressure associated with fracture screenout, and these screenout events can emerge at different places along the fracture. Next, because of the lack of pretreatment geomechanical data, the values of layer stress and leakoff coefficient are adjusted for a field case so that the varying bottomhole pressure and fracture length are in line with the field measurements. This paper provides a useful illustration for hydraulic-fracturing treatments with proppant transport affected by and interacting with reservoir lithological complexities.
- Oceania > Australia (0.46)
- Asia > China (0.28)
- North America > United States (0.28)
- Geology > Rock Type (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Oceania > Australia > Queensland > Surat Basin (0.99)
- Oceania > Australia > New South Wales > Surat Basin (0.99)
Abstract Fracture growth in layered formations where the stresses and rock mechanical properties change frequently with depth is of great interest to researchers, especially when estimating the vertical growth of fractures in hydraulic fracturing treatments. The influence of formation stresses on fracture growth has been well documented and supported by numerous case histories, but the height-growth limitations resulting from intersection and crossing of various interfaces by the fracture continues to be investigated. This paper describes a model and a method to predict potential locations where a horizontal fracture can develop and limit the vertical growth of the fracture. Most height growth predictions using traditional pseudo-3D (P3D) models result in planar fractures of widths that vary depending on the stresses and mechanical property of the layers that the fracture crosses. As evinced from the literature and laboratory experiments, the propagating cracks may have a three-dimensional (3D) characteristic given the observed combination of deviation (kinking) and out-of-plane displacements that can hinder the vertical growth. Multiple flaws leading to a 3D crack can be approximated as a two-dimensional (2D) model by considering it as a mixed boundary value triple pressurized-crack problem. In this paper, such representations are first used to obtain discrete stress intensity factors (SIF) at specific locations, and then, are superimposed on routine SIFs to include the influence of real-world 3D cracks on vertical growth estimation. Fracture width profiles across several layers were generated using a modified equilibrium height growth model and were key to identifying the regions where complex growth in layered formations could potentially exist. These predictions resemble the analog for 3D fractures and given the fact that a portion of the treatment was injected at pressures that exceeded the overburden, alludes to the presence of a horizontal fracture component. Micro-seismic survey from the treatment shows vertical growth containment at the location where minimal width is projected. Three cases histories where these observations were made are also presented in the paper along with pertinent theory and explanations. The model developed in the study is helpful in predicting potential locations where a horizontal fracture can develop and limit the vertical growth or even curtail the extension of the main fracture. The method developed in the study requires discrete layered formation and fluid properties such as stresses, rock moduli, SIFs, leakoff, and fracturing fluid rheology, as the only inputs, and hence can be applied to a variety of examples worldwide.
- Europe (0.93)
- North America > United States > Texas (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.46)
- Oceania > Australia > Queensland > Surat Basin (0.99)
- Oceania > Australia > New South Wales > Surat Basin (0.99)
- North America > United States > Texas > Maverick Basin > Sacatosa Field (0.99)
- (3 more...)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- (3 more...)
Integrated Hydraulic Fracture Geometry Evaluation Based on Pre-Cambrian Tight Silicylate Reservoir in South Oman Salt Basin
Smirnov, Dmitrii (Petroleum Development Oman) | Isaee, Omar AL (Petroleum Development Oman) | Moiseenkov, Alexey (Petroleum Development Oman) | Al Hadhrami, Abdullah (Petroleum Development Oman) | Shabibi, Hilal (Petroleum Development Oman) | Kaabi, Saqer (Petroleum Development Oman) | Sayapov, Ernest (Petroleum Development Oman)
Abstract Pre-Cambrian South Oman tight silicilyte reservoirs are very challenging for the development due to poor permeability less than 0.1 mD and laminated texture. Successful hydraulic fracturing is a key for the long commercial production. One of the main parameter for frac planning and optimization is fracture geometry. The objective of this study was summarizing results comparison from different logging methods and recommended best practices for logging program targeting fracture geometry evaluation. The novel method in the region for hydraulic fracture height and orientation evaluation is cross-dipole cased hole acoustic logging. The method allows to evaluate fracture geometry based on the acoustic anisotropy changes after frac operations in the near wellbore area. The memory sonic log combined with the Gyro was acquired before and after frac operations in the cased hole. The acoustic data was compared with Spectral Noise log, Chemical and Radioactive tracers, Production Logging and pre-frac model. Extensive logging program allow to complete integrated evaluation, define methods limitations and advantages, summarize best practices and optimum logging program for the future wells. The challenges in combining memory cross-dipole sonic log and gyro in cased hole were effectively resolved. The acoustic anisotropy analysis successfully confirms stresses and predominant hydraulic fractures orientation. Fracture height was confirmed based on results from different logging methods. Tracers are well known method for the fracture height evaluation after hydraulic frac operations. The Spectral Noise log is perfect tool to evaluate hydraulically active fracture height in the near wellbore area. The combination of cased hole acoustic and noise logging methods is a powerful complex for hydraulic fracture geometry evaluation. The main limitations and challenges for sonic log are cement bond quality and hole conditions after frac operations. Noise log has limited depth of investigation. However, in combination with production and temperature logging provides reliable fit for purpose capabilities. The abilities of sonic anisotropy analysis for fracture height and hydraulic fracture orientation were confirmed. The optimum logging program for fracture geometry evaluation was defined and recommended for replication in projects were fracture geometry evaluation is required for hydraulic fracturing optimization.
- Asia > Middle East > Oman (0.72)
- North America > United States (0.47)
- Geology > Geological Subdiscipline (0.94)
- Geology > Sedimentary Basin > Salt Basin (0.40)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Passive Seismic Surveying (0.48)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (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 > Production logging (1.00)
Fracture Height Prediction Model Utilizing Openhole Logs, Mechanical Models, and Temperature Cooldown Analysis with Machine Learning Algorithms
Khan, Abdul Muqtadir (Schlumberger) | BinZiad, Abdullah (Saudi Aramco) | Subaii, Abdullah Al (Saudi Aramco) | Bannikov, Denis (Schlumberger) | Ponomarev, Maksim (Schlumberger) | Parkhonyuk, Sergey (Schlumberger)
Abstract Vertical wells require diagnostic techniques after minifrac pumping to interpret fracture height growth. This interpretation provides vital input to hydraulic fracturing redesign workflows. The temperature log is the most widely used technique to determine fracture height through cooldown analysis. A data science approach is proposed to leverage available measurements, automate the interpretation process, and enhance operational efficiency while keeping confidence in the fracturing design. Data from 55 wells were ingested to establish proof of concept.The selected geomechanical rock texture parameters were based on the fracturing theory of net-pressure-controlled height growth. Interpreted fracture height from input temperature cooldown analysis was merged with the structured dataset. The dataset was constructed at a high vertical depth of resolution of 0.5 to 1 ft. Openhole log data such as gamma-ray and bulk density helped to characterize the rock type, and calculated mechanical properties from acoustic logs such as in-situ stress and Young's modulus characterize the fracture geometry development. Moreover, injection rate, volume, and net pressure during the calibration treatment affect the fracture height growth. A machine learning (ML) workflow was applied to multiple openhole log parameters, which were integrated with minifrac calibration parameters along with the varying depth of the reservoir. The 55 wells datasets with a cumulative 120,000 rows were divided into training and testing with a ratio of 80:20. A comparative algorithm study was conducted on the test set with nine algorithms, and CatBoost showed the best results with an RMSE of 4.13 followed by Random Forest with 4.25. CatBoost models utilize both categorical and numerical data. Stress, gamma-ray, and bulk density parameters affected the fracture height analyzed from the post-fracturing temperature logs. Following successful implementation in the pilot phase, the model can be extended to horizontal wells to validate predictions from commercial simulators where stress calculations were unreliable or where stress did not entirely reflect changes in rock type. By coupling the geometry measurement technology with data analysis, a useful automated model was successfully developed to enhance operational efficiency without compromising any part of the workflow. The advanced algorithm can be used in any field where precise fracture placement of a hydraulic fracture contributes directly to production potential. Also, the model can play a critical role in cube development to optimize lateral landing and lateral density for exploration fields.
- Asia > Middle East > UAE (0.28)
- North America > United States > Texas (0.28)
- Geology > Rock Type (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (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)
Using New Intervention-less Surveillance Technology to Optimize the Implementation of Waterflood
Al Anbari, Ali (Petroleum Development Oman) | Al Harthi, Mahmood (Petroleum Development Oman) | Choudhury, Suryyendu (Petroleum Development Oman) | Borkent, Evert-Jan (Petroleum Development Oman) | In ‘T Panhuis, Petrus (Petroleum Development Oman) | Hemink, Gijs (Petroleum Development Oman) | Al Yahmadi, Mundhr (Petroleum Development Oman) | Abdul Abbas, Hawra (Petroleum Development Oman) | Morianta, Marpaung (Petroleum Development Oman)
Abstract The value of implementing intervention-less downhole surveillance technology lies in early assessment of field-scale reservoir performance and well deliverability in South Oman's largest waterflood development. Such technology can aid in assessing whether aquifer support by means of (controlled) fracture injection is achievable, which is potentially more valuable than matrix injection to enhance oil production. At the same time HSSE exposure and deferment will be reduced by avoiding well interventions. This paper will share learnings from Distributed Fiber-Optic (FO) Sensing technology. More specifically, this paper will present the case study of field ‘A’, where waterflood is being operated in two methods based on sectors depending on field geological and reservoir properties: ‘Deep’ water injection in the aquifer, under fracture conditions ‘Shallow’ water injection close to the oil-water-contact (OWC), under matrix conditions ‘Deep’ water injection minimizes the risk of early water breakthrough, but it delays the aquifer pressure support which in turn means lower offtake. The ‘Shallow’ water injection (trialed by injecting water 50m below OWC) has a higher risk of water short circuiting, accelerates pressure support and thereby enhances production / well deliverability. Fiber-optic data is part of a decision-based surveillance program, which also included injection / production logging via PLT, step-rate tests, and pressure monitoring. The time-lapse data has illustrated some fracture growth up- and downwards of the perforation interval in most wells but is still contained below the OWC. In some wells, the injection growth is also controlled by the presence of several intra-reservoir shale baffles that are acting as barriers to vertical communication and thereby delaying the injection response while inducing a strong pressure response in nearby producers. The data has helped to further calibrate and validate the model assumptions and will help in optimizing the waterflood development concept for the field. Proactive interventional-less surveillance enables monitoring of the zonal injection conformance, provides advantage of learning reservoir performance and supports agile WRFM operations and decision making. Furthermore, cost competitive and credible technology have made PDO a front runner to keep subsurface risk at as low as reasonably practical levels and boost oil production. This distributed fiber optic sensing technology provided cost-effective, fit-for-purpose, and intervention-less well-and-reservoir surveillance.
- Asia > Middle East > Oman (0.26)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.16)
- Information Technology > Communications > Networks (1.00)
- Information Technology > Security & Privacy (0.91)