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Carbonate reservoirs
Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- Research Report > New Finding (0.93)
- Overview (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Mineral (0.72)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- (2 more...)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
Full Registration Fee (begins from 21 April 2024 onwards) US 1690.5 (Member) US 1942.5 (Non-member) Written notice received by 20 April 2024 entitles registrants to a full refund of the registration fee minus US 50 for processing. No refunds will be issued after 20 April 2024. Substitutions are permissible with written approval by the event organizers. Notify Anneke de Klerk ([email protected]) immediately to request a substitution. The workshop will be of interest to geophysicist, reservoir engineers, geologists, asset engineers, regulatory bodies, researchers/academia.
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (0.40)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (0.40)
- North America > United States > Texas (1.00)
- Europe (0.93)
- Research Report > New Finding (0.93)
- Overview (0.88)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.47)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
All material in this report, with accompanying figures, is property of SEG Advanced Modeling Corporation (SEAM). License to use the data and models can be obtained through SEAM. This document contains contributions from many different individuals and has been reviewed for accuracy. Reported errors will be fixed on a timely basis. The SEAM Carbonate model is the petroleum industry's first field-scale, digital model of a carbonate reservoir to be openly available.
- Geology > Rock Type > Sedimentary Rock (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
Microfluidics for Carbonate Rock Improved Oil Recovery: Some Lessons from Fabrication, Operation, and Image Analysis
Duits, Michel H. G. (University of Twente, Physics of Complex Fluids Group (Corresponding author)) | Le-Anh, Duy (University of Twente, Physics of Complex Fluids Group) | Ayirala, Subhash C. (Exploration and Petroleum Engineering Center - Advanced Research Center (EXPEC ARC)) | Alotaibi, Mohammed B. (Exploration and Petroleum Engineering Center - Advanced Research Center (EXPEC ARC)) | Gardeniers, Han (University of Twente, Mesoscale Chemical Systems Group) | Yousef, Ali A. (Exploration and Petroleum Engineering Center - Advanced Research Center (EXPEC ARC)) | Mugele, Frieder (University of Twente, Physics of Complex Fluids Group)
Summary After the successful implementation of lab-on-a-chip technology in chemical and biomedical applications, the field of petroleum engineering is currently developing microfluidics as a platform to complement traditional coreflooding experiments. Potentially, microfluidics can offer a fast, efficient, low-footprint, and low-cost method to screen many variables such as injection brine composition, reservoir temperature, and aging history for their effect on crude oil (CRO) release, calcite dissolution, and CO2 storage at the pore scale. Generally, visualization of the fluid displacements is possible, offering valuable mechanistic information. Besides the well-known glass- and silicon-based chips, microfluidic devices mimicking carbonate rock reservoirs are currently being developed as well. In this paper, we discuss different fabrication approaches for carbonate micromodels and their associated applications. One approach in which a glass micromodel is partially functionalized with calcite nanoparticles is discussed in more detail. Both the published works from several research groups and new experimental data from the authors are used to highlight the current capabilities, limitations, and possible extensions of microfluidics for studying carbonate rock systems. The presented insights and reflections should be very helpful in guiding the future designs of microfluidics and subsequent research studies.
- North America > United States (1.00)
- Asia > Middle East (0.67)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.81)
- Geology > Mineral > Carbonate Mineral > Calcite (0.53)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (4 more...)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
The focus of this workshop was to share selected case studies, emerging monitoring techniques, and mapping dynamic behavior of the reservoir and their impact on production and economics of carbonate fields. Based on the success of the workshops held in 2011 and 2013, this third edition aims to capitalize on lessons learned by linking integrated feasibilities and pilot designs to reduce uncertainties in reservoir monitoring and management.
- Asia > Middle East > Kuwait (0.27)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.18)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Abstract Binary surfactant systems have demonstrated superior oil recovery capabilities in enhanced oil recovery (EOR) applications compared to single surfactant systems. This is due to their ability to form mixed micelles, which exhibit lower interfacial tension (IFT) and greater solubilization capacity than single surfactant systems. Thus, understanding their interactions and properties is crucial for maximizing their beneficial effects and determining their synergism. Therefore, in this study, we conducted a systematic experimental study involving eight surfactants and six binary surfactant mixtures at various ratios to determine their critical micelle concentrations (CMCs). Additionally, we applied Rubingh's Regular Solution Theory to characterize the behavior of these binary surfactant mixtures and to assess potential interactions among the surfactants. Our findings reveal a consistent synergistic phenomena in all binary surfactant systems, with the concentration of non-ionic surfactants playing a crucial role. Increasing the non-ionic surfactant concentration improved synergistic interactions, resulting in low CMC when combined with anionic, cationic, and zwitterionic surfactants. However, an excess concentration of the cationic surfactant exhibited "weak" synergistic effects, which can be attributed to its relatively smaller hydrophobic tail. Introduction Carbonate reservoirs, constituting more than 60% of the world's hydrocarbon reserves, are of significant importance for efficient oil production (Adibhatla & Mohanty, 2006). These reservoirs often exhibit a high degree of heterogeneity, complex pore structures, and substantial presence of impurities. Some carbonate formations are further complicated by high reservoir temperatures and high salinity conditions (Lu et al., 2014). These pose significant challenges in reservoir characterization, production, and management. Consequently, oil recovery in these reservoirs frequently falls below 40% (Høgnesen et al., 2005). Historically, surfactants have been utilized in enhanced oil recovery (EOR) applications, displaying promising outcomes (Ahmadi & Shadizadeh, 2013; Ivanova et al., 2020). Surfactants, being amphiphilic molecules, effectively reduce the interfacial tension (IFT) between oil and water that in turn enables the mobilization of trapped oil within the reservoir and its displacement towards production wells (Bello et al., 2022). However, a significant limitation in the application of single surfactants in carbonate formations arises from the presence of impurities like clay minerals and the physiochemical conditions of the aqueous medium, such as salinity and pH, which can influence the surface charge of the rock, and might lead to unfavorable results (Pal et al., 2018). This calls for the exploration of alternative strategies, such as binary surfactant solutions. Binary surfactant systems involve the combination of two distinct surfactants, each with its unique properties and behaviors.
- Asia (0.68)
- Europe > Norway > Norwegian Sea (0.24)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 211167, “Selective and Reversible Water-Shutoff Agent Based on Emulsion System With Nanoparticles Suitable for Carbonate Reservoirs at High-Temperature and High-Salinity Conditions,” by Masashi Abe, SPE, Jumpei Furuno, and Satoru Murakami, Nissan Chemical Corporation, et al. The paper has not been peer reviewed. _ The complete paper presents the evaluation results of a water-shutoff (WSO) agent based on an emulsion-type chemical material with nanoparticles. The WSO agent, which the authors call an emulsion system with nanoparticles (ESN), has several advantages to existing polymer and gel materials, including high thermal stability, low sensitivity to mineralization, thixotropic characteristics, selectivity of blocking effects for oil and water, and reversibility of blocking effects. In WSO applications, these properties of ESN could be well-suited for improved oil recovery. Introduction ESN is recognized as a proven technology for carbonate reservoirs. However, the reservoir under study did not feature harsh conditions; therefore, this work evaluated ESN potential for carbonate reservoirs in the UAE typically having high-temperature and high-salinity conditions. A primary purpose of the technology, aside from improved oil recovery, is contributing to greenhouse-gas emission reduction and building competitive low-CO2-intensity oil-brand value. In general, produced water volume dramatically increases in maturing oil fields. Reducing water production also can contribute to saving water injection from a reservoir-voidage-replacement viewpoint. Therefore, the functional chemical WSO concept has a significant effect on contributing to the International Energy Agency’s sustainable development scenario. Materials and Physicochemical Property Tests Oil, Water, and Carbonate Core. Dead oil is sampled from an offshore carbonate field in the Middle East containing light crude oil (32.3 °API). Brine and plug core properties are summarized in Tables 1 and 2 of the complete paper. For thermal-stability tests, both brines were used for making the ESN. The WSO coreflood tests used the ESN made with injection water. Advanced Features of ESN. Rheology. The viscosity of ESN is controllable by changing the water/oil ratio; viscosity becomes lower with increasing oil content and higher with increasing water content. These components were stirred, and two ESN samples were prepared using Crude Oil A (from Oil Field A, UAE) or diesel oil. The samples are referred to as Crude Oil A-based ESN and Diesel Oil-based ESN in this paper. Both ESN samples showed similar viscosity curves; such thixotropic characteristics are an important property of ESN. ESN is flowable at stirring conditions. In particular, the viscosity of ESN can be decreased to less than 50 cp at high shear rates, so it can be injected into the reservoir by pumping. On the other hand, ESN becomes highly viscous and less flowable when no energy is applied to it (the ESN surface looks semisolid in this condition). In field operations, the viscosity of ESN decreases depending on the pressure generated by injection pumps on the surface. However, the injection pressure also releases in a radial direction from the bottomhole zone. As a result, ESN recovers a high-viscosity state because of decreasing shear rate with pressure release.
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
Unleashing Thermal Potential: Successes and Challenges in Steam Injection Well Completions for Thermally Assisted GOGD Heavy Oil Field
Nofali, N. (Petroleum Development Oman, Muscat, Oman) | Amri, M. (Petroleum Development Oman, Muscat, Oman) | Shaibani, M. (Petroleum Development Oman, Muscat, Oman) | Vandeweijer, T. (Petroleum Development Oman, Muscat, Oman) | Diri, M. (Petroleum Development Oman, Muscat, Oman)
Abstract Field-X is a heavily naturally fractured carbonate reservoir with viscous and sour oil. The recovery mechanism employed is thermally assisted gas oil gravity drainage (TA-GOGD), featuring a unique combination of a gas cap and strong aquifer influx—making it the first and only of its kind worldwide. The objective of this paper is to showcase the success stories and challenges associated with steam injection well completions in this unique and challenging producing environment. The focus is on the entire well completion process, including design, installation, remedial interventions, and operation, with a specific emphasis on maintaining well integrity and meeting field steam injection targets. Real case studies are presented, highlighting the success stories and challenges of steam injection well completions in Field-X. The improvements made in completion design are discussed, ranging from injection through cemented casing to sophisticated completions, and the challenges encountered with each design are also emphasized. Additionally, the learnings and challenges during the workover interventions using well pulling hoist (WPH) or wireline unit (WLU) are highlighted. Furthermore, operational philosophy and best practices for well integrity are presented, drawing on cumulative field experience. The Improved completion design has resulted in enhanced injection performance, improved well integrity, and consequently increased oil recovery and production. However, emerging issues that require further attention and mitigation are also identified. Additionally, the paper concludes by highlighting valuable lessons learned and providing recommendations concerning steam injection well interventions and operational strategies. Real case studies and valuable guidance are offered for optimizing steam injection well completions, contributing to the understanding of optimizing thermal recovery in similar carbonate reservoirs.
- Asia > Middle East (0.29)
- North America > Canada (0.28)
- 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 > Improved and Enhanced Recovery > Thermal methods (1.00)