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Shawn Maxwell is the President and Chief Technology Officer of IMaGE, Itasca Microseismic and Geomechanical Evaluation products and services. Prior to joining Itasca, he was the Chief Geophysicist and Microseismic Advisor at Schlumberger, and has also led technology development at Pinnacle/Halliburton and ESG, and as a Lecturer at Keele University in England. Shawn was awarded a Ph.D. specializing in Microseismology from Queen's University in Kingston, Canada. Maxwell has authored numerous engineering and geophysical papers highlighting all aspects of microseismic acquisition, processing, and interpretation, with a particular emphasis on practical application to engineering challenges. He serves on various microseismic-focused committees and workshops around the globe, is the CSEG Education Director, and chairs the CSEG Microseismic User Group.
- North America > Canada > Ontario > Kingston (0.27)
- Europe > United Kingdom > England > Staffordshire (0.27)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Microseismic interpretation is the monitoring of small scale microseismic signals made from either natural or man made tremors. Most widely used to estimate stimulated reservoir volumes and in identifying major fault or fracture events for use in hydrocarbon exploration. Since its advent around the year 2000, microseismic interpretation/monitoring (MSI/MSM) has greatly increased the geological understanding of fracture propagation, especially in that of hydrocarbon reservoirs. What this article will be going over are the main steps in the quality control evaluation of the acquired microseismic data. The first step in MSI is figuring out the level of uncertainty regarding the event location.
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Micro-Fracturing in SCB Test: Acoustic Emission Analysis
Petruลพรกlek, Matej (Institute of geology of the Czech Academy of sciences, Czech Republic) | Aminzadeh, Ali (Institute of geology of the Czech Academy of sciences, Czech Republic) | Lokajรญcek, Tomรกลก (Institute of geology of the Czech Academy of sciences, Czech Republic) | Vavrycuk, Vรกclav (Institute of Geophysics of the Czech Academy of Sciences, Czech Republic) | Jechumtรกlovรก, Zuzana (Institute of Geophysics of the Czech Academy of Sciences, Czech Republic) | Kolรกr, Petr (Institute of Geophysics of the Czech Academy of Sciences, Czech Republic) | Rott, Josef (Faculty of Science, Charles University, Sprรกva ลพeleznic, stรกtnรญ organizace, Czech Republic) | Neลพerka, Vรกclav (Czech Technical University in Prague, Czech Republic) | Somr, Michael (Czech Technical University in Prague, Czech Republic)
ABSTRACT: Mode I fracture toughness test was performed on the Cotta sandstone on semi-circular bend specimen in a symmetric geometry. The twenty-two channels were used for acoustic emission (AE) monitoring during the loading up to the failure. This study presents a detail AE analysis focused on the better understanding of micro-mechanisms leading to formation of fracture process zone (FPZ) and the following fracture propagation. The interpretation was based on the stress-induced changes in locations and source mechanisms of AEs. As a result, the micro-cracking can be divided into three following intervals: FPZ initiation, FPZ formation and fracture propagation. Each separate interval has its different AE characteristics that are presented in this paper. INTRODUCTION From the point of LEFM, and considering significantly lower resistance to tensile stress for rocks, the mode I fracture toughness (KIC) is one of their key material properties. There are several laboratory tests recommended for its estimation (see ISRM suggested methods). Recently, the semicircular bending test (SCB) is becoming a more common way for estimating the KIC (Kuruppu et al., 2014). Among its advantages are easy specimen preparation and rather straightforward interpretation. However, several researchers have reported a significantly lower KIC estimated from SCB tests, when compared to the other methods (see references in Wei et al., 2016). A rather larger fracture process zone (FPZ) in the SCB tests may be a responsible for this inconsistency (Tutluoglu and Keles, 2011; Kuruppu et al., 2014). The FPZ can be defined as a highly cracked area, surrounding the tip of the crack, at the moment just before it becomes unstable and starts to propagate (Zang and Wagner, 2000). There are several ways for experimental estimation of FPZ size, with the DIC and AE methods being the more reliable ones (e.g. Lin et al., 2019). In this paper, we applied the detail AE analysis to interpret the micro-cracking induced by the axial loading during the SCB test performed on the fine-grained Cotta sandstone. Based on the different AE characteristics, the micro-cracking can be divided into three separate intervals: (i) FPZ initiation; (ii) FPZ formation; (iii) fracture propagation. Each separate interval has its different AE characteristics that are presented in this paper.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.47)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Managing New Development Uncertainty with Scenarios and Multiscale Modelling: An Integrated Study of the Fogelberg Discovery
Mullins, James R. (Rock Flow Dynamics, Aberdeen, UK) | Mendez, Maria (Rock Flow Dynamics, Aberdeen, UK) | Bajan, Luka (Lime Petroleum AS, Oslo, Norway) | Rocher, Dimitri (Lime Petroleum AS, Oslo, Norway) | Spitzmรผller, Adam (Lime Petroleum AS, Oslo, Norway) | Marsh, Tom (Rock Flow Dynamics, Aberdeen, UK) | Berntsen, Bjรธrn A. (Lime Petroleum AS, Oslo, Norway)
Recent hydrocarbon developments are generally characterised by high complexity and uncertainty with lower margins for error in an unpredictable financial market. This is further compounded by new oil and gas discoveries being typically smaller today, than in the past; highlighting the need for robust and fit-for-purpose reservoir models that accurately capture key uncertainties to inform management decisions and to help avoid substantial financial losses. To make an informed decision on either field development or relinquishment of the Fogelberg production license on the Norwegian Continental Shelf (NCS), an alternative full field reservoir model was commissioned by one of the License partners of a complex stacked tidal bar system in the Norwegian Sea. The model includes an accurate representation of the underlying heterogeneities observed in a drill stem test (DST) performed in 2018, incorporating the spatial evolution of the tidal bar system including the placement of low permeability inter-bars to stylolitisation at core-plug scale. Furthermore, the model is robust enough to permit future forecasting and well planning required to enable a management decision. A scenario-based modelling approach (after Bentley and Smith, 2008) based on three discrete concepts was undertaken, accounting for uncertainty in the spatial geometry of the tidal bar complexes. This approach was combined with a hierarchical modelling strategy to honour the depositional concept model and to provide modelling flexibility. Sub-cell resolution heterogeneity in the form of stylolites that were prevalent in cored intervals were incorporated using a multi-scale approach in the form of a representative elementary volume (REV). A full uncertainty ensemble was generated for each of the three modelling scenarios. The model produced a robust match to the bottom hole pressure (BHP) reported during the DST and was used to generate production potential and optimize lower completion strategy, including a side-by-side comparison of recovery of horizontal wells with fishbone stimulation, hydraulic fracturing stimulation and unstimulated slotted liner completions. Based on new static and dynamic understanding of the reservoir, the license will be re-applied for with a view to future development. This paper highlights the importance of managing uncertainty through the use of scenarios, their flexibility with ensembles and the use of a multi-scale approach to accurately represent the respective lengths at which heterogeneities occur to build a better knowledge of the subsurface. The work undertaken for this petroleum system is both highly relevant and transferable for the future transition of safe and permanent storage of carbon, hydrogen and nuclear storage.
- Geology > Sedimentary Geology > Depositional Environment (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.66)
- Geology > Structural Geology > Tectonics > Extensional Tectonics (0.46)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL S86 > Melke Formation (0.99)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL 199 > Block 6506/11 > Kristin Field > Tofte Formation (0.99)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL 199 > Block 6506/11 > Kristin Field > Ile Formation (0.99)
- (13 more...)
- Well Drilling > Drilling Operations (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- (8 more...)
Abstract As the industry continues pushing capital efficiency and chasing increasing lateral lengths, the odds of crossing subsurface faults or deformation zones rise. Some features can present different challenges than others. This study in the Midland Basin focuses on a strike-slip fault/deformation zone traversing a seven-well development. Although large-scale faulting is not as common in the Midland Basin as in other basins such as the Eagle Ford and Haynesville, they still present challenges that must be recognized and potentially mitigated. Deformation zones can lead to an unwanted connection to formations with higher water cuts or zones bearing H2S. From the completion perspective, deformation zones can also act as superconductive highways for frac fluids, leading to a loss of stimulation effectiveness and potentially less efficient capital deployment (Kerr et al., 2022). This study presents a possible mitigation technique to alleviate some of these economic, safety, and development concerns. Introduction This study area is located in the northern part of the Midland basin (Figure 1a). Oil and gas development in this area includes wells in multiple targets within the Spraberry and Wolfcamp formations (Figure 1b). The San Andres, approximately one thousand feet below the surface, is a permeable dolomite enhanced by fracture permeability related to syndepositional margin collapse and reactivation of older faults during the Laramide Orogeny (Wilson et al., 2019). Over the last decade, the San Andres has been utilized as a salt-water injection formation. This injection of produced water into the San Andres has led to pressure gradient differences (Sanchez et al., 2019). These conditions are not only potential drilling hazards but can lead to vertical and lateral migration of the produced waters being injected in large quantities. Produced water injection promotes the growth of sulfate-reducing bacteria, which leads to the generation of hydrogen sulfide (H2S) as well as iron sulfides in producing wells. These can lead to serious safety concerns as well as implications for the optimized production of oil and gas reservoirs.
- Geology > Mineral > Sulfide (0.76)
- Geology > Structural Geology > Tectonics (0.54)
- Geology > Structural Geology > Fault > Strike-Slip Fault (0.34)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.69)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (29 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- (3 more...)
ABSTRACT Natural fractures and faults result from the tectonic and structural history of rock formations. While laterally extensive fracture networks can increase the depletion area, they can create challenges due to fluid channeling-pressure communication. Electrical imaging is used at the wellbore to identify fractures/faults. However, interpreting open features is difficult in oil-based mud (OBM) as they can appear resistive. Ultrasonic images lose sensitivity in the presence of spirals, drill marks, or non-homogeneous mud. The borehole acoustic imaging uses 3-dimensional slowness time coherence and ray tracing to determine far-field reflectors, providing acoustic reflectors dip/azimuth and their distance away from wellbore. Combining these two it can provide a reflectors map of fractures and faults but cannot confirm their openness. To address this, we present a method that uses Hayman image to assist analyzing open fractures/faults. Correlating the wellbore fracture/fault planes with 3D slowness time coherence and ray tracing (sonic far field) based event, we interpreted the extension of fractures and faults from the wellbore into the formation on surface seismic aligned section and identified potential pressure communication channels. In OBM, MHz frequency imager data can produce resistivity, dielectric permittivity, and standoff images through advanced inversion processing. By combining dielectric and resistivity information, a new Hayman image can be generated through post-processing. Jointly analyzing resistivity and Hayman images helps resolve open/partially open features even when borehole rugosity is high, and other imaging techniques lose sensitivity. Mapping these identified fractures/faults and interpreted potentially unstable fractures away from the wellbore wall helped in identifying the orientations and alignments of the wellbore and far-field events on surface seismic aligned sonic migrated image. A joint interpretation of resistivity and Hayman images (pilot well) identified two additional open/partially open fractures in the upper-middle section, along with several closed fractures and two closed faults. In the middle of the well there is a depth interval where closed fracture density increases compared to above and below. This interval is identified as an unstable zone from the borehole image. Comparing with the far field sonic processed results, this unstable interval has the highest density of sonic reflectors. The azimuth of the open fractures interpreted from the image upper section is in alignment with a side-track well open fractures interpreted in the unstable zone. In this case study, we identified open and unstable closed fractures intervals that extend into the formation and can form a pressure communication channel when the well is put into injection. These observations were consistent with field pressure communication and substantiated with production logging measurements. This spatially resolved fracture network is essential for subsurface understanding and future well placement in this field, providing critical input for the dynamic reservoir model.
- Europe > Norway > North Sea (0.28)
- Asia > Middle East > UAE (0.28)
- North America > United States > Texas (0.28)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/8 > Valhall Field > Tor Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/8 > Valhall Field > Hod Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/11 > Valhall Field > Tor Formation (0.99)
- (6 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- (4 more...)
- South America (1.00)
- North America > Canada (1.00)
- Europe > United Kingdom (1.00)
- (8 more...)
- Personal > Honors (1.00)
- Overview (1.00)
- Instructional Material > Course Syllabus & Notes (1.00)
- (3 more...)
- Geology > Geological Subdiscipline (0.93)
- Geology > Structural Geology > Tectonics (0.92)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Borehole Geophysics (0.92)
- (2 more...)
- Law (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- Government > Regional Government > Asia Government (1.00)
- (7 more...)
- North America > United States > Utah > Sage Field (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- (28 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Management > Professionalism, Training, and Education > Personnel competence (1.00)
- (12 more...)
Abstract The first microseismic monitoring operations of hydraulically stimulated wells were run in Bahrah and Sabriyah oilfields, Northeastern Kuwait. The main objective was to evaluate the capacity of the microseismic in optimising the fracturing process and consequently improving the production of these reservoirs. The major phases of such monitoring projects are sensors network design, deployment, acquisition, data processing, results delivery, and interpretation. Fit-for-purpose monitoring networks were designed by modelling the expected sensitivity and location accuracy of various sensors geometry scenarios, considering local reservoir properties. Geophones were deployed in observation wells nearby treatment wells to record the seismic waves emitted by the microearthquakes induced by the rock fracturing process. This seismicity was located and characterised to image the fracture networks growth under the effect of pumping. From this, fracture geometry parameters were assessed, stress and hazard characterised, unexpected behaviours were monitored and analysed. By providing information in real-time during rock stimulation operations, microseismic monitoring successfully helped improving production while maintaining a focus on the risk assessment indicators. In Bahrah, seismic response to the treatment was assessed for the target carbonate formation Mauddud, evaluating stimulation effectiveness while characterising unexpected and unwanted behaviours. In Sabriyah, fracture geometry estimates helped calibrating injection models and fine-tuning stimulation plans. Furthermore, a strong focus was also placed on monitoring hazard and anomalies in the Tuba carbonate formation being stimulated near a natural fault. Monitoring procedure, results and lessons learned from these projects can be transferred to other existing or upcoming wells to be drilled in the same formations, adding value to these reservoirs by optimising the fracture design, and making hydrocarbon recovery safer and more efficient. This paper reports on the first usage of microseismic monitoring in Bahrah and Sabriyah oilfields in Kuwait. Monitoring met the initial objectives and both the approach as well as results are now a baseline for the effective development of hydraulic stimulation in these reservoirs and others with similar characteristics.
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.94)
- Geology > Geological Subdiscipline > Geomechanics (0.68)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Najmah Formation (0.99)
- (18 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Information Technology > Communications > Networks (0.54)
- Information Technology > Architecture > Real Time Systems (0.34)
A Catalogue of Fiber Optics Strain-Rate Fracture Driven Interactions
Ugueto, Gustavo (Shell Exploration and Production Company) | Wu, Kan (Texas A&M University) | Jin, Ge (Colorado School of Mines) | Zhang, Zhishuai (Chevron) | Haffener, Jackson (Devon Energy) | Mojtaba, Shahri (Apache) | Ratcliff, David (ResFrac) | Bohn, Rob (Halliburton) | Chavarria, Andres (OptaSense) | Wu, Yinghui (Silixa) | Guzik, Artur (Neubrex) | Srinivasan, Aishwarya (Texas A&M University) | Gibson, Richard (Halliburton) | Savitski, Alexei (Shell Exploration and Production Company)
Abstract The downhole monitoring of strain using Fiber Optics (FO) can reveal unique information about the propagation and geometry of hydraulic fractures between nearby wells during stimulation and production. This work aims at creating a catalogue of commonly observed strain-rate signals captured in a not yet stimulated nearby observation well equipped with either a permanently or temporarily installed FO cable. This catalogue is the result of an informal collaboration between experience FO users from academia, service providers, consulting companies, and operators. In the creation of this first edition of a strain-rate catalogue, we considered two main types of stimulation categories (single and multi-entry) as well as the angle between the hydraulic fractures and the segment of the well where the strain-rate signals are observed (horizontal vs. vertical segments). In the catalogue we show a series of representative examples of two main types of far-field strain Fracture Driven Interactions (s-FDI) commonly encountered in frac diagnostics: 1. Vertical hydraulic fractures being monitored in a lateral portion of a horizontal well and 2. Vertical fractures being monitored in a vertical observation well. The catalogue is organized around commonly observed s-FDI motifs. Because interpretation of observed strain-rate signals can be subjective, when possible, we included observed examples with a brief description of our interpretation, as well as synthetic signals from geomechanical models of similar motifs. The strain-rate motifs were modeled based on first physical principles for rock deformation. These models serve to support the proposed interpretation of the observed signals. FO strain rate monitoring is changing our understanding about the hydraulics fracturing process. The information from FO strain is not available by other commonly used fracture diagnostic techniques. Strain- rate fractures driven interactions between wells occur in predictable patterns (Frac Domain and Stage Domain Corridors โ FDC & SDC respectively) which are typically in line with the cluster spacing and stage length in the borehole being stimulated. Using FO strain monitoring, we now know that hydraulic fractures are larger than first anticipated, both in length and height. Many examples indicated that there is a direct correspondence between the near-field and far-field stimulation geometries. The lack of isolation due to cement quality and or plug failure manifests in the far-field geometries observed via FO strain-rate in nearby wells. The use of FO strain monitoring has also revealed that reopening of hydraulic fractures is common not only between prior and infill wells but also between wells from the same stimulation vintage. All these observations and conditions must be considered when interpreting new strain-rate datasets and more importantly when designing new hydraulic fracturing operations and considering different stimulation order (zipper schedule), as well as when making decisions about the vertical and lateral spacing of adjacent wells. The purpose of this industry-first edition strain-rate catalogue is to aid, new and experienced FO users, on the interpretation of strain-rate datasets. Ultimately, the accurate interpretation of FO strain data will not only help calibrate geomechanical and reservoir models but also directly influence where and how we complete unconventional wells. Nowadays, many s-FDI examples exist in scattered publications with formats that arenโt easily comparable for new users of the technology. In this project, we expand upon those publications to create an encompassing analysis with up-to-date interpretations where we have formalized the formatting of figures for better readability (color scheme, scales, etc.). What has resulted from this collaborative effort is a novel catalogue not available before in the FO published literature.
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- (33 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- (3 more...)
Azimuthal Investigation of a Fractured Carbonate Reservoir
Bouchaala, F. (Khalifa University of Science and Technology (Corresponding author)) | Mohamed, Aala A. I. (Khalifa University of Science and Technology) | Jouini, M. S. (Khalifa University of Science and Technology) | Bouzidi, Y. (Khalifa University of Science and Technology) | Ali, M. Y. (Khalifa University of Science and Technology)
Summary Oil production and enhanced oil recovery in carbonate reservoirs in Abu Dhabi, UAE, are largely affected by fracture systems that control the fluid path and the permeability of reservoirs. Most fracture properties, such as fracture orientations and density, are obtained by interpreting petrophysical data acquired at the wellbores, whereas fracture properties between wells are typically derived from nonzero offset seismic data. However, deriving fracture properties from seismic data is challenging, as it requires a robust methodology and a careful seismic processing procedure. In the current case study, we used the azimuthal amplitude vs. offset (AVAz) method on 3D seismic data acquired in onshore Abu Dhabi, to generate maps of fracture orientation and density in a carbonate reservoir. A sophisticated processing series was carefully performed to increase signal-to-noise ratio (SNR) and preserve seismic amplitudes. The main parameters controlling the AVAz method were investigated and optimized before being applied to the 3D seismic data. The reservoir has a high fracture density in the lower regions, but a low fracture density in the upper parts, indicating a weaker anisotropy. The resulting dominant fracture directions span from north-northwest/south-southwest to north-northeast/south-southwest, as well as from northwest/southeast to east/west, which is consistent with the primary fracture orientations determined from the interpretation of fullbore formation microimager (FMI) data acquired at well locations. These fracture systems are the result of the Late Cretaceous obduction of the Semail ophiolite, which was oriented east/west and northeast/southwest, followed by the south/north to southwest/northeast trending Late Oligocene-Miocene continent-continent collision of the Arabian and Central Iran plates along the Zagros orogenic front.
- Phanerozoic > Cenozoic > Paleogene > Oligocene (0.54)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.45)
- Geology > Structural Geology > Tectonics > Plate Tectonics (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.34)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Abu Dhabi Field (0.98)
- Asia > Middle East > Saudi Arabia > Thamama Group Formation (0.98)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)