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Collaborating Authors
carbonate reservoir
A deep-learning framework for borehole formation properties prediction using heterogeneous well-logging data: A case study of a carbonate reservoir in the Gaoshiti-Moxi area, Sichuan Basin, China
Lin, Lei (China University of Geosciences) | Huang, Hong (China Petroleum Logging Corporation Limited) | Zhang, Pengyun (China Oilfield Services Limited) | Yan, Weichao (Frontiers Science Center for Deep Ocean Multispheres and Earth System) | Wei, Hao (China University of Geosciences) | Liu, Hang (China Petroleum Logging Corporation Limited) | Zhong, Zhi (China University of Geosciences)
ABSTRACT The properties of borehole formations, such as porosity, permeability, and water saturation, play a crucial role in characterizing and evaluating subsurface reservoirs. Although core sample experiments offer precise measurements, they are time consuming and cost intensive. An alternative method is to use the logging data to construct an empirical model that predicts formation properties, which is widely studied due to its speed and affordability. Nevertheless, because the response of a logging point reflects its surrounding formation, conventional logging methods relying on point-to-point (P2P) mapping perform poorly in complex reservoirs. Furthermore, the resolution of conventional logging is lower compared with imaging logging. To address these limitations, this study presents a novel approach to predict formation properties based on a deep-learning framework using heterogeneous well-logging data. Our neural network framework takes short sequences of conventional logging data and windowed imaging logging data as inputs. The neural network applies 1D convolution to extract features from the conventional logging sequences and 2D convolution to extract features from the resistivity imaging data. Then, these two feature vectors are fused and fed into a multilayer fully connected neural network to predict formation properties. A case study of a carbonate reservoir demonstrates that our method delivers more accurate predictions of formation porosity, permeability, and water saturation than the P2P, sequence-to-point, and image-to-point prediction methods. Moreover, it is expected that our paradigm will serve as a source of inspiration for forthcoming research endeavors aimed at enhancing the accuracy of predicting borehole formation properties in complex reservoirs.
- Geology > Structural Geology > Tectonics (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.46)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.70)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > China Government (0.46)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- North America > United States > Louisiana > China Field (0.99)
- Asia > Pakistan > Sindh > Khairpur District > Indus Basin > Kadanwari Field (0.99)
- (3 more...)
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)
This forum provided an open discussion on carbonate reservoir characterization and monitoring. By far the largest and most extensive petroleum reservoirs worldwide exist in carbonate reservoirs, chiefly located in the Middle East. As these reservoirs mature it becomes imperative that we apply advanced geophysical and reservoir engineering technology to evaluate, monitor, and ultimately manage these important resources. This five-day meeting in Bahrain examined the geological and geophysical characteristics of carbonate reservoirs and the role of geophysics in characterizing and managing them.
- 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)
_ 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.
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.
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)
Application of Ultra-High Speed Rotating Shoes Offshore Indonesia - A Case History
Nkwocha, C. (Geopro Oilfield Technologies, Houston, Texas, United States of America) | Hermawan, A. (Petronas Indonesia, Jakarta, Indonesia) | Fauzan, A. Z. (Petronas Indonesia, Jakarta, Indonesia) | Ardhiansyah, F. (Petronas Indonesia, Jakarta, Indonesia) | Mahadhir, S. (Petronas Indonesia, Jakarta, Indonesia)
Abstract This paper presents two recent cases studies for high-speed rotating shoes in the East Java Sea of Indonesia where extended reach wells have been successfully drilled and completed. Rotating shoes have been used to successfully deploy 5½ inch lower completion strings in Well A, Well B, and Well C, in 2020, 2022, and 2023 respectively. Well A had the 9⅝ inch casing shoe at 15,492 feet MD with the final depth of 16,480 feet MD. Well B is currently the longest 8½ inch production lateral drilled (6,207 feet) in Indonesia at the time of this paper with a final well depth of 15,685 feet MD. The 9⅝ inch production casing shoe was set at 9,478 feet MD. Well C was eventually completed at a final depth of 14,305 feet MD with 9⅝ inch casing shoe at 10,662 feet MD. All laterals were drilled as 8½ holes and completed as 5½ inch oil producers. In Well A, a rotating shoe was used as a contingency due to its high ERD ratio in comparison to previous wells drilled in the field up until that time. In Well B string rotation was not a feasible option due to well profile and the 5½ inch completions string configuration, hence the need for rotating shoes. In Well C well bore stability issues across zones prone to loss circulation resulted in multiple sidetracks from the primary borehole, one of which was carried in the production section, thus predicating the use of a rotating reamer shoe for the 5½ lower completion. Well C was eventually completed with the third sidetrack, at a final depth of 14,305 feet MD with the 9⅝ inch production casing shoe set at 10,662 feet MD. The liner hanger was successfully set with an estimated savings over $700K for successfully deploying the lower completions Well C as estimated cost of an additional clean-out run. One reason running lower completions in these wells are successful is the use of high-speed rotating shoes. When required the rotating shoe was able to ream through obstructions while guiding the completion string into and through the drilled hole to TD. Rotating shoes are still very new to the industry and adoption is slow. However, from our experience it is evident that deployment requires appreciation of the technology and the underlying principles that make it effective, thus creating an enabling environment for proper application is paramount. This requires collaboration between end-user and supplier with good understanding of well engineering principles because the service provider will be key to a successful operation. This paper focuses on the completion operations leading to the successful deployment of the 5½ inch lower completion strings in both Wells B and C.
- Asia > Middle East > UAE > Abu Dhabi Emirate (0.30)
- Asia > Indonesia > East Java (0.25)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Bab Field > Thamama Group Formation (0.99)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency > East Java Basin > Southwest Java Basin (0.99)