Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Results
Identification of Bitumen with Pyrolysis Analysis on Core/Cuttings and NMR Relationship in Middle Marrat Reservoir Rock
Shoeibi, Ahmad (Geolog International) | Al-Hashash, Meshari (Kuwait Oil Company) | Al-Ajmi, Saad (Kuwait Oil Company) | Odreman, Allan Stefanic (Kuwait Oil Company) | Sanclemente, Milton (Geolog International) | Bonetti, Antonio (Geolog International)
ABSTRACT The primary objective of this study is to demonstrate the correlation between bitumen presence identified using Pyrolysis analysis in core/cuttings, and petrophysical data from NMR logs in the Jurassic Marrat Formation, Kuwait. Since the presence of bitumen in the reservoir presents a barrier to flow and is additionally responsible for damage to formation quality, the identification of bitumen intervals is critical for effective well completion design and development strategies in the Middle Marrat reservoirs of North Kuwait. In this study, several core, and cuttings samples from the Middle Marrat were analysed with geochemical methods, in particular XRD and Pyrolysis, so as to provide characterisation of both mineralogy and organic matter allowing the determination of bitumen presence. Due to the compact size and robustness of the analytical equipment employed, the analyses could be performed on-site. NMR logging was employed in many of the well intervals under consideration. The comparison between porosity derived from NMR logs and that derived from neutron/density logs was used to indicate the presence of solid bitumen. The results from four wells drilled within the same field are presented in this paper. In each reservoir section, the Pyrolysis analysis was applied to core, cuttings, or both. Measurements performed on cuttings were affected by contamination from oil-based drilling fluid, affecting S1 and in some cases also S2 peak determination. However, by employing sample cleaning using organic solvents, it was possible to remove these contaminants while retaining the insoluble bitumen component. The post-treatment Pyrolysis analysis was able to accurately determine the amount of residual bitumen present in the cuttings. Petrophysical interpretation of the NMR and other open hole logs indicated the presence of bitumen in the same intervals where Pyrolysis analysis had identified bitumen. However, in one of the wells the NMR tool failed while logging and in another, the logging was cancelled due to borehole conditions. These scenarios are not uncommon due to well path complexity and borehole instability, leaving the surface analysis of cuttings/core as the only method able to detect bitumen intervals in the reservoir, even in the presence of oil-based mud. This research represents the first characterisation of Middle Marrat reservoir including bitumen detection by means of Pyrolysis on cuttings/core, integrated with NMR log interpretation. The correlation between the two techniques is seen to validate the Pyrolysis approach, demonstrating the possibility to rely on the method when logs are not available. The resulting bitumen interval identification can be the key to a successful reservoir management, implementing completion strategies that maximize flow contribution from the greatest possible extent of net pay.
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.35)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (1.00)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > Oil sand/shale/bitumen (1.00)
Summary This study provides an extensive critical review of electromagnetic heating (EMH) methods [inductive heating (IH), low-frequency heating (LFH), and high-frequency heating (HFH)] to highlight their existing challenges in enhanced heavy-oil and oil sands recovery. In general, IH is considered to be less practicable than LFH and HFH. The resistance (ohmic or conduction) heating prevails in LFH while dielectric heating prevails in HFH. Thus, the effectiveness of LFH decreases if reservoir water is overheated to generate steam. Also, the intensity of the energy released and the temperature rise in LFH are not as significant as those in HFH. LFH also fails in penetrating the media with breaks, heterogeneities, and in partially saturated media (e.g., when some oil saturation has been produced). These challenges might somewhat be remedied by HFH at the expense of reducing the electromagnetic (EM) wave penetration depth. The advantages of HFH include remote heating through a desiccated reservoir region around the EM energy source, higher intensity of the energy released and greater temperature rise, and better EM wave penetration through partially saturated media with breaks and heterogeneities. The caveat, however, is that the practical application of HFH could be more expensive than LFH. Besides, the lower depth of EM wave penetration in HFH remains a challenge. During HFH, the temperature increase occurs as a result of the induced molecular rotation in the dielectric material, in particular if the material contains more polar compounds. The polar molecules follow the EM field. This increases the internal molecular friction within the material and generates heat, leading to the rise of temperature. Because the heat generated is a function of the stored (absorbed) energy in the reservoir, the dielectric constant or the real permittivity of the reservoir should be enhanced to enhance the performance of HFH. This ensures that the temperature has risen reasonably in a reasonable amount of time with a reasonable amount of electricity consumption. However, to generate a uniform rise in temperature on a large scale away from the wellbore, the imaginary permittivity of the material should be reasonably lowered, too, for maximizing the penetration of the EM wave (while the real permittivity is an indication of the degree of polarization, the imaginary permittivity is associated with dielectric losses). Lowering the imaginary permittivity away from the wellbore helps minimize the effects of steam condensation (condensate formation retards the EM wave propagation) or delay steam condensation because the reservoir temperature is reduced during the later stages of oil production. The thermal conductivity of the formation should also be enhanced, especially away from the wellbore to generate a more uniform rise in temperature. These three reservoir improvements (enhancing real permittivity, lowering imaginary permittivity, and enhancing thermal conductivity) in an attempt to enhance EMH underpin the rationale behind proposing future optimizations of EMH, and in particular, HFH.
- South America (1.00)
- North America > United States > Texas (1.00)
- Europe (1.00)
- (4 more...)
- Research Report > New Finding (0.93)
- Overview (0.67)
- South America > Colombia > Llanos Basin (0.99)
- North America > United States > Wyoming > Green River Basin (0.99)
- North America > United States > Utah > Green River Basin (0.99)
- (10 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > Oil sand/shale/bitumen (1.00)
Data-Driven Integrated Reservoir Development of a Mature Condensate-Rich Gas Field in the Sultanate of Oman
van Gilst, Roeland (Petroleum Development Oman PDO) | Al Kindi, Ahmed (Petroleum Development Oman PDO) | Al Balushi, Naila (Petroleum Development Oman PDO) | Abri, Al Mutasem (Petroleum Development Oman PDO) | Al Busaidy, Ahmed (Petroleum Development Oman PDO) | Al-Khusaibi, Aida (Petroleum Development Oman PDO)
Abstract Recent observations indicate a distinct hydrocarbon composition change in a mature condensate rich gas field in the Sultanate of Oman, which will drastically change the next development decisions. The new insights were a result of: 1) data analysis and visualization and 2) collaboration between Development Planning (DP), Well & Reservoir Management (WRM) and Exploration. Field data such as well tests, fluid samples and production logging tests were integrated with geological concepts to deliver reservoir models that could assist late field life decision making. The outcome of the data analysis was summarized in the so-called "Plumbing Diagram", which combines reservoir architecture, structural elements, fluid fill and a reservoir connectivity analysis. The diagram was also used as a collaboration tool between Development, WRM and Exploration, which enabled the non-core team members to quickly understand the key uncertainties, risks and opportunities. Field data indicated vertical changes in hydrocarbon composition across the field. These new observations were combined with exploration burial diagrams and thin section analysis from core data. This led to the insight that the gas field is not just rich in condensate, but has gone through various hydrocarbon charge stages starting with an initial oil charge. A recently drilled well confirmed the existence of the oil charge with solid bitumen indicating a subsequent thermal cracking phase. Integration with wire line log evaluations made it possible to define two field-wide fluid zones, referred to by the team as: 1) Free Gas (FG) and 2) Condensate Rich Gas (CRG). The split of the two fluid zones will have a major impact on the field Development and WRM strategy as the focus is shifting towards development of the CRG zone, which is more challenging mainly due to the fluid fill mixture of oil, bitumen, gas and condensate. This paper describes how field data, observations and collaboration between teams improved the total hydrocarbon system understanding driving the future development decisions. The success of the changes in the development and WRM strategy will serve as blueprint for condensate rich gas fields with a similar burial and charge history in the north of Oman.
- North America > Canada > Alberta > Stettler County No. 6 (0.82)
- North America > Canada > Alberta > Starland County (0.82)
- North America > Canada > Alberta > Red Deer County (0.82)
- North America > Canada > Alberta > Kneehill County (0.82)
- Geology > Sedimentary Geology (0.94)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.77)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.47)
- Geophysics > Borehole Geophysics (0.89)
- Geophysics > Seismic Surveying (0.69)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (0.89)
- (4 more...)
Identification of Patches of Bitumen in a Carbonate Reservoir: A Case Study
Igogo, Arit (ADNOC Onshore) | El Sahn, Hani (ADNOC Onshore) | Khan, Sara Hasrat (ADNOC Onshore) | Bhushan, Yatindra (ADNOC Onshore) | Al Mazrooei, Suhaila Humaid (ADNOC Onshore) | Lehmann, Christoph (ADNOC Onshore) | Alwahedi, Mohamed Abdulhameed (ADNOC Onshore)
Abstract Carbonate reservoir X has varying levels of maturity in terms of development. The South/West is highly matured; development activities have recently kicked-off in the Crestal part while the areas towards the Far North is not fully developed and posed the largest uncertainty in terms of reservoir quality, fluid contacts, oil saturation, well injectivity/ productivity, area potential and reserves due to poor well control. In reservoir X with segmented development areas, patches of bitumen have been found in the Far North. The extent of this Bitumen was unknown. In order to expand the CO2 development concept to achieve production target from the Far Northern flank, an understanding and mitigation of the area uncertainties is crucial. Reservoir bitumen is a highly viscous, asphaltene rich hydrocarbon that affects reservoir performance. Distinguishing between producible oil and reservoir bitumen is critical for recoverable hydrocarbon volume calculations and production planning, yet the lack of resistivity and density contrast between the reservoir bitumen and light oil makes it difficult, if not impossible, to make such differentiation using only conventional logs such as neutron, density, and resistivity. This paper highlights the utilization and integration of advanced logging tools such as nuclear magnetic resonance and dielectric, in conjunction with routine logs, pressure points, RCI samples, vertical interference test and core data to differentiate between reservoir bitumen and other hydrocarbon types in the pore space. The major findings from the studies shows bitumen doesn't form as a single layer but occurs in different subzones as patches which is a challenge for static modelling. When high molecular weight hydrocarbons are distributed in the pore space and coexist with light and producible hydrocarbons, reservoir bitumen is likely to block pore throats. The Bitumen present in this reservoir have a log response similar to conventional pore fluids. The outcome of this study has helped in refining the bitumen boundary, optimize well placement, resolved the uncertainties associated with deeper fluid contacts and provided realistic estimate of STOIIP.
- Research Report > Experimental Study (0.49)
- Research Report > New Finding (0.48)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > Oil sand/shale/bitumen (1.00)
Summary The heavy-oil- and bitumen-recovery process by injection of a pure condensing solvent in a solvent vapor chamber provides an alternative to steam-based recovery techniques such as steam-assisted gravity drainage (SAGD). Because of the lower operating temperature between 40 and 80ยฐC, the process uses a much lower energy budget than a steam process and thus results in significantly reduced greenhouse-gas emissions. This paper describes the route to a successful production function with the physical processes at play and using analytical tools. Physical relationships are derived for the solvent/bitumen (S/B) ratio, the bitumen drainage from the roof of the solvent vapor chamber, and for bitumen extraction from both sides of the solvent chamber by the draining condensed solvent. The fast diffusion of bitumen into this narrow liquid solvent zone is likely subtly enhanced by transverse dispersion. The speed of bitumen extraction from the roof of the solvent vapor chamber is constrained by the gas/oil capillary pressure. Extraction from the side of the chamber is approximately three times faster by the action of the thin gravity-draining liquid solvent film. Several equations are provided to enable creation of a heat balance for this condensing solvent process. Laboratory and field observations are matched, including the rates, the heat balance, and the S/B ratio. The model can explain constrained production performance by identifying the rate-limiting steps (e.g., when insufficient solvent condenses). The model predicts high solvent holdup during the rise of the solvent chamber. A method to estimate this solvent liquid saturation is provided. The S/B ratio depends on injector-wellbore heat losses, the (high) liquid saturation in the rising solvent chamber, and the process properties (operating temperature), reservoir properties (heat capacity, porosity, and oil saturation), and solvent properties (density and latent heat). In the existing body of literature, no satisfactory analytical model was available; this new approach helps to constrain production performance and to estimate solvent and heat requirements. The methods in this paper can be used in the future for subsurface project design and performance predictions.
- North America > United States > Texas (0.67)
- Asia (0.67)
- North America > Canada > Alberta (0.46)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > Oil sand/shale/bitumen (1.00)
Interpretation of Electromagnetic Wave Penetration and Absorption for Different Reservoir Mineralogy Quartz-Rich, Limestone-Rich, and Clay-Rich and at High and Low Water Saturation Values for a Bitumen Reservoir
Morte, Matthew (Texas A&M University) | Alhafidh, Hasan (Texas A&M University) | Hascakir, Berna (Texas A&M University)
Abstract Electromagnetic (EM) waves are used in the oil and gas industry to identify the geology of the formation and the type of the fluid saturating the medium. There is also an interest to use the electromagnetic waves as an enhanced oil recovery (EOR) method. However, interpretation of logging data generated through electromagnetic waves or determination of the electromagnetic wave propagation in a medium as an EOR method are not easy tasks. This study aims to identify the role of different geological settings with different types of fluid saturations in the response of electromagnetic wave propagation and absorption. To reach this objective multitude-systematic laboratory scale experiments were conducted on different reservoirs fluid and rock pairs. As reservoir mineralogy, different grain size of quartz, clay, or limestone is used to prepare the reservoir rocks at different porosity. Water is known as a good absorber for EM waves, thus, pore space were saturated at different water saturations and a bitumen sample (10,000 cP, 12ยฐ API) from Canada. Prepared samples were packed into in-house-built-Plexiglas core holder which allows measurements with EM waves. The response of EM waves propagation and absorption was measured by using a vector network analyzer at varying frequencies (500 MHz to 4 GHz) through dielectric properties (dielectric constant, loss tangent, and penetration depth). The results were used to obtain correlations between dielectric properties and physical properties (reservoir rock mineralogy, porosity, water saturation, and oil saturation) of the reservoir rock-fluid blends. Water saturation gives a perfect correlation with dielectric constant and loss tangent values of the saturated medium. Because dielectric constant and loss tangent parameters provide an idea on the absorption characteristics of EM wave in the medium, and because water is a strong EM wave absorber, as it was expected, with the increase in water saturation, the dielectric constant and loss tangent parameters of the medium are also increased; on the other hand, penetration depth was decreased. With the increase in quartz content in the medium, it has been observed that EM wave penetration is enhanced. As a result, several correlations were created in this study and they can be used to better interpret the reservoir mineralogy and fluid saturation as a response to EM wave logging. Moreover, these results can be used to estimate the effective area (penetration depth) of EM wave as an EOR method in different mediums.
- North America > United States (0.93)
- North America > Canada > Alberta (0.28)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Mineral > Silicate > Phyllosilicate (0.92)
- (2 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (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)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > Oil sand/shale/bitumen (1.00)
Abstract This paper describes a novel approach in drilling production wells while implementing real-time mapping of the Bitumen-Water Contact (BWC) with extra-deep azimuthal resistivity (EDAR) logging while drilling (LWD) service, thereby resulting in an increase of exploited bitumen reserves by optimizing wellbore placement. Within the Athabasca Bitumen Reservoir, the EDAR LWD service confidently mapped the BWC within a range of 2-22 meters below the entire producer wellbore. It also provided an earlier warning of an approaching low resistivity boundary, which allowed the operator to optimize the wellbore placement using real-time proactive steering decisions. In contrast to the existing azimuthal resistivity tools, which have the limited depth of investigation, this approach significantly mitigated the risks of intersecting or giving an incomplete picture of BWC surface. The real-time interpretation of extra-deep azimuthal resistivity data provided better understanding of the lateral distribution of the McMurray Formation along the horizontal wellbore, lithologically varying from clean sand facies to mud-filled channel facies and inclined heterolithic stratification (IHS) facies. The fluid heterogeneity of the reservoir included partial reservoir charging, irregular BWC and lean zones, which compounded lithology complexity within the reservoir. In one of the case studies, 50 percent increase was achieved in actual exploited bitumen reserves in comparison to the projected exploited reserves if drilled per the planned trajectory. This new LWD approach was proven effective while drilling horizontal appraisal and producing wells in unconsolidated formations with high reservoir heterogeneity, it offered an opportunity to better understand the bitumen reservoir and ultimately led to increased production performance of Oil Sands projects.
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.61)
- Well Drilling > Drilling Measurement, Data Acquisition and Automation > Logging while drilling (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > Oil sand/shale/bitumen (1.00)
Technology Focus Since the last Reservoir Performance and Monitoring feature in September 2016, the industry trends of significantly improving efficiency and reducing operational costs have continued to be implemented. For instance, at the time of writing, in North America, the US oil rig count has risen impressively for 23 straight weeks and the big players have greatly reduced their exposure to Canadaโs oil sands. However, while many efforts are focusing on the optimization of current technologies and the study of past reservoir performance to improve future developments, with fewer capital resources and personnel available, these efforts may yield only incremental improvements. Technology and innovation are seen industrywide as critical to long-term radical efficiency and productivity. Once the industry becomes less concerned about cost savings and more about investing in future technologies and long-term performance, the nonrisk-averse innovation culture from other industries could help us develop new disruptive technologies and implement them in the field. For instance, with the proper resources in place, automated reservoir-performance modeling and monitoring may no longer be a science-fiction scenario. Once this downturn appears in the rear-view mirror, our industry will need to change its model disruptively to thrive sustainably in the next growth cycle. During the past 12 months, 160 technical papers were presented at various conferences and meetings with reservoir-performance-and-monitoring programs and were reviewed for this feature, displaying further advances in reservoir-performance monitoring, analysis, and optimization. The papers selected and recommended as additional reading are representative samples of the reviewed papers. They are a geographically diverse mix of academic work, industrial research and development, and field applications, describing numerical simulation and laboratory research, field-data-acquisition and -interpretation studies, new-technology development and field trials, and multi-year reviews of current technologies and work flows. Recommended additional reading at OnePetro: www.onepetro.org. SPE 181550 Current State and Future Trends in the Use of Downhole Fluid Analysis for Improved Reservoir Evaluation by H. Elshahawi, Shell, et al. SPE 184131 Production Optimization Through Voidage Replacement Using Triggers for Production Rate by Cenk Temizel, Aera Energy, et al. SPE 183195 Development of Crosswell Electromagnetic Monitoring System Usingย the HTS-SQUID Magnetometer by Makoto Harada, Japan Oil, Gas, and Metals National Corporation, et al.
- North America > Canada (0.73)
- Asia > Japan (0.55)
- Geophysics > Magnetic Surveying > Magnetic Acquisition (0.57)
- Geophysics > Electromagnetic Surveying (0.55)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Real-time optimization (0.84)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (0.57)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > Oil sand/shale/bitumen (0.57)
Since the last Reservoir Performance and Monitoring feature in September 2016, the industry trends of significantly improving efficiency and reducing operational costs have continued to be implemented. For instance, at the time of writing, in North America, the US oil rig count has risen impressively for 23 straight weeks and the big players have greatly reduced their exposure to Canada's oil sands. However, while many efforts are focusing on the optimization of current technologies and the study of past reservoir performance to improve future developments, with fewer capital resources and personnel available, these efforts may yield only incremental improvements. Technology and innovation are seen industrywide as critical to long-term radical efficiency and productivity. Once the industry becomes less concerned about cost savings and more about investing in future technologies and long-term performance, the nonrisk-averse innovation culture from other industries could help us develop new disruptive technologies and implement them in the field.
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Real-time optimization (0.65)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (0.58)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > Oil sand/shale/bitumen (0.58)
The electromagnetic heating of oil wells and reservoirs refers to thermal processes for the improved production of oil from underground reservoirs. The source of the heat, generated either in the wells or in the volume of the reservoir, is the electrical energy supplied from the surface. This energy is then transmitted to the reservoir either by cables or through metal structures that reach the reservoir. The main effect, because of the electrical heating systems used in practice in enhanced oil recovery, has been the reduction of the viscosity of heavy and extra heavy crudes and bitumens, with the corresponding increase in production. This chapter mainly considers those systems (and the models that describe their effects) that have been used for the electromagnetic heating in the production of extra heavy petroleum and bitumen. The importance of these hydrocarbons is because of the size of the heavy oil reserves in Canada, Venezuela, countries of the former U.S.S.R., the U.S.A., and China.[1]
- South America > Venezuela (1.00)
- Europe (1.00)
- North America > United States > Massachusetts (0.46)
- (3 more...)
- South America > Venezuela > Zulia > Maracaibo Basin > Tia Juana Field (0.99)
- South America > Venezuela > Jobo Field (0.99)
- Asia > China > Tianjin > Bohai Basin > Huanghua Basin > Dagang Field (0.99)
- Well Completion > Completion Installation and Operations (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (6 more...)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)