bluuebunny/crossref_metadata_2025_split huggingface dataset:
Brine to Enhance the Transport of Encapsulated Petroleum Sulfonates Nanosurfactants Deeper into the High Temperature Carbonate Reservoirs
Authors: Gizzatov Ayrat , Kawelah Mohammed , Mashat Afnan , Abdel-Fattah Amr I. 
Published: March 2022

Abstract
Development of NanoSurfactants (NSs), encapsulated petroleum sulfonates, is in progress for use as one of the most cost efficient surfactants in chemical enhanced oil recovery (CEOR) applications under extreme conditions. This work provides a better understanding of NS transport though porous carbonate rocks and demonstrates how hot and salty brines can facilitate NS transport when compared to deionized (DI) water.
Transport of NSs at 90 °C in 57,000 ppm total dissolved solids (TDS) brine as well as NS components, petroleum sulfonate and zwitterionic co-surfactant, in 90 °C DI water through limestone core plugs was studied using a core flood apparatus. Effluent samples were measured for the total surfactant concentration using a total organic carbon (TOC) analyzer, and the dynamic retention values were calculated and compared. Structural integrity of NS assemblies before and after transport through the porous rock structure were studied using 1H Nuclear Magnetic Resonance (NMR) spectroscopy.
Petroleum sulfonate surfactants are unstable in hot brines with high concentrations of divalent ions, and therefore cannot be transported through porous rock structures. Transforming such unstable sulfonates into NS formulations can overcome these challenges. Dynamic retention results in water-wet limestone demonstrate that NSs can be successfully transported through 150 - 200 millidarcy (mD) reservoir rocks with retention values &lt; 0.4 mg/g of rock. These values are 30-50% lower than the retention of NS components alone, which is &lt; 0.7 mg/g, if measured at the same conditions using DI water. Much lower retention for NSs was observed in brines, when compared to its surfactant components in DI water. This can be attributed to the NSs nanostructure which is designed to encapsulate sulfonates closer to the core while efficiently dispersing in the brines by co-surfactants with zwitterionic heads located at the surface. High salinity brine also helps to screen surface charges present on the rock surface. NMR spectroscopy results confirm that the nano-assembled NS structure does not exhibit noticeable changes after core flood experiments and confirms that the formulation has great potential for CEOR applications.
Results presented in this work demonstrate that NS formulations made of assembled and dispersed nanocapsules enable the application of one of the lowest cost industrial surfactants for CEOR in hot and salty brines. This formulation in brines significantly reduces the loss of surfactants to the carbonate rock when compared to the same surfactant components in fresh water.
Shock/Soaking Injection Scheme to Improve Oil Recovery in Carbonate Formations by Low Salinity Water Flooding
Authors: Marzhan Karimova , Peyman Pourafshary , Mahmood Fani 
Published: March 2022

Abstract
The application of low salinity water and ion management of the injected water affects the oil recovery in carbonate formations. Different forced and spontaneous imbibition experiments have been practiced on the carbonate core samples to show the performance of this smart water injection. Various experimental and modeling approaches have been applied by different researchers to optimize the smart waterflooding process. To achieve more practical conditions, the injection time of the smart water should be reduced to control the preparation cost on the field scale. In this paper, we present findings from different modeling/experimental studies to improve the performance of smart water flooding in carbonate formations by the idea of shock/soaking.
Different researches showed that the presence of active ions such as Mg2+ and SO42- in the injection water alters the wettability of carbonates to more water-wet state and also reduces the IFT between the oil and the injected brine. Hence, spiking active ions concentration in the low salinity water improves oil recovery from carbonate formation. In this work, the optimized smart brine was used for injection with novel injection scheme. The optimized brine was set to be injected as the shock slug between two slugs of high salinity water. This smart water shock flooding was designed to reduce the pore volume of low salinity water flooding. The effect of the slug on relative permeability curves was modeled and analyzed in the core and sector scales. Also we experimentally studied the effect of soaking time after the shock on wettability alteration and improvement in recovery by re-injection of high salinity normal brine.
Characterization tests such as contact angle measurement confirmed the effect of shock/soaking on alteration of governing mechanisms such as multi-ion exchange which leads to wettability alteration in the process. Our core flooding experiments showed that the shock injection at the best design can improve the tertiary recovery up to 7.8%. Also, modeling at the reservoir sector shows noticeable incremental oil recovery during the shock injection and high salinity water injection after it.
Our modeling/experimental studies clearly illuminated a new approach to improve the performance of low salinity water flooding in an efficient and cheaper way. By this approach, higher oil recovery can be achieved by the application of less amount of diluted water which is beneficial for the oil industry.
Investigating Non-Newtonian Multiphase Cutting Transport in an Extended Reach Well
Authors: Khan Muhammad Saad , Barooh Abinash , Khan Muhammad Yousuf , Rahman Mohammad Aziz ur , Hassan Ibrahim , Hassan Rashid 
Published: March 2022

Abstract
In horizontal drilling, inefficient hole cleaning causes multiple operational issues and increased pressure loss. In-situ measurement of the cutting transport is essential to understand the hydrodynamics and operational parameters required for the effective hole cleaning. The electrical resistance tomography (ERT) is becoming a promising tool in many industrial applications. The purpose of this study was to provide detailed information about the application of non-invasive ERT system to analyze the volume fraction of solids in the presence of non-Newtonian fluid (0.5 wt% Flowzan) in a drilling annulus. The experiments were conducted in a horizontal flow loop system where the annulus section was 240 (6.16 m) inch long contains the inner and outer diameters of 2.5 inch (6.4 cm) and 4.5inches (11.4 cm), respectively. The obtained results suggested that the ERT system could effectively detect the volume fraction of the solids in the presence of non-Newtonian fluid (Flowzan) at different drilling conditions. Results also revealed that with an increase in fluid velocity, the efficient hole cleaning was observed. Moreover, the drill pipe rotation also positively influenced the cutting transport. Therefore, this study will provide the avenue for the industrial application of in situ ERT measurement technique in the multiphase systems, especially in the presence of the non-Newtonian drilling fluids.
Sea-Fastening Analysis and Design of a Horizontally Transported Large Jacket
Authors: Gorrela Vinod kumar 
Published: March 2022

Abstract
Due to advances in the maritime industry and the availability of a wide range of transportation barges, jackets are now being fabricated far from installation sites. They are commonly towed from fabrication yards to installation sites. This paper focuses on the innovative techniques and methodologies used for the seafastening design during such transportations.
During transportation, the jacket will experience inertial loads due to barge motions. The intensity of these loads depends on various environmental factors (wave height, wind speed, for example). Additionally, the barge will experience hogging and sagging that results in large concentrated loads at the tie-down locations. Therefore, in order to eliminate unnecessary conservatism, it is essential to also include the structural behavior of the jacket during the tow and design the seafastening members accordingly.
The most significant finding is that the hogging and sagging deflections are significantly decreased by considering the jacket stiffness in the transportation analysis. This results in a more practical & optimized seafastening design. A detailed comparison of the numerical model with and without the jacket stiffness is provided to illustrate this stiffening effect.
In addition, for launch jackets, the actual value of the timber stiffness is applied between the jacket launch rail and the barge skid beam. Furthermore, appropriate load dispersion is assumed vertically through this arrangement. These features are critical when estimating the actual loads that will be transmitted to the barge transverse frames and bulkheads.
It is concluded that the stiffness and load path play an essential role in the seafastening design and barge strength checks. Therefore, this paper discusses its importance by considering an actual jacket transportation case study.
The analysis methodology provides practical recommendations to evaluate the actual stiffness of the entire system for the jacket transportation. Conservatisms in the seafastening design are minimized and this results in a more pragmatic design approach.
A Novel Robust Polymer Gels for Water Shutoff Application in Sandstone Reservoir
Authors: Almohsin Ayman , Hung Jin , Bataweel Mohammed , Abadi Abdullah 
Published: March 2022

Abstract
Polymer gels is an effective method for water shut-off (WSO) application in sandstone oil reservoirs having high water cuts. WSO application can extend the economic life of the field once the undesired water production is minimized. A novel polymer gel was developed for water shut-off applications that extend the limitations of the current available materials for sandstone formation.
The new developed system offers chemical bonding of an organically crosslinked polymer gel to the sandstone rock surface, enabling the water shutoff system having enhanced stability with superior performance. The fluid system is low toxic and environmentally acceptable. It is comprised of polymer gel and adsorption components for sandstone formation, In order to enhance the blocking efficiency of WSO polymer gel, specific adsorption component for sandstone formation was introduced into the organically crosslinked polymer (OCP) gel. The gelant can be placed as a single phase, low-viscosity solution into the targeted formation zones. The new Polymer gel
Lab rheology study of the new developed polymer gel reveals that both the gelation time and the formed gel strength were greatly affected by the addition of the sandstone adsorption component. By using the appropriate retarder, the gelation time can be controlled without compromising gel strength. The new polymer gel was placed in haigh permeability sandstone core plug, and chase water was subseqyently injected to measure bloking capasity. The core flow test indicates substantial drops in water prduction. The new polymer system was able to withstand 3500 psi differential pressures at 200°F and did not allow the flow of water inside the core sample.
The new polymer gel system is expected to control water production through high permeability streaks and large pore openings. The system can be injected in porous media without injectivity reduction due to their low initial viscosity. This work provides significant insight using polymer gel system as an effective chemical treatments intended for carbonate substrate as water shutoff material.
Detection of Drilling Loss Zones in Deep Gas Well Using Acoustic and High Precision Temperature Logging Technology, a Case Study from North of Oman
Authors: AbdelAzim Mohamed , Galin Nail , Abri Ahmed , Khanbashi Iman , Shamsi Khalsa , Badar Zeidi , Pranava Ananda , Rodger Chris 
Published: March 2022

Abstract
The X-field is located in the North West of Oman. Drilling of more than 30 appraisal and development vertical wells is planned in the coming few years. Whilst drilling through the carbonate formations of Habshan, Jubaila and Tuwaiq Mountain in the existing 11 wells, total to partial mud losses were encountered in several wells due to the severe karstification. This led to significant cost increases and delays to the well delivery time.
Utilizing the new wide azimuth seismic data and well maps, gives an indication of a loss zone intervals using the seismic attributes to assess the possibility of encountering the loss zone. The detection of the source of losses presents a big challenge; knowing the precise zones helps in optimizing the number of cement curing plugs thus a reduction in drilling days and cost.
When losses occur; the drilling fluid moves from high pressure side (mud weight) to low pressure side (formation) causing a complete loss, where it expands rapidly and produces a turbulent flow that creates an acoustic signal and temperature anomaly. Modern acoustic logging tools, Chorus acoustic platform (Spectral Noise Log – SNL), coupled with fast and high precision temperature logging tools, Cascade thermal platform (High Precision Temperature – HPT), are capable to detect the subsequent acoustic and temperature anomalies in the drilling losses and indicate the loss zones.
The chorus acoustic platform contains a new generation, high-sensitivity hydrophone – a piezo crystal element that records noise in a wide frequency range (0.1-60kHz). The Cascade thermal platform utilizes a super-sensitive platinum sensor with a response time of less than one second. The technology is already being used in critical oil and gas wells to identify tubing and casing leaks and address well integrity issues but, this is the first time it has been used in the open hole to identify the drilling mud losses in Oman.
This paper presents the successful use of Chorus and Cascade platforms (SNL-HPT) in a Deep Gas well in X-Field, North of Oman, PDO Company, for identifying the total and partial loss zone across 12.25" hole.
The well-A was drilled as an appraisal vertical gas deep well in one of X fields, North of Oman, and experienced fluid losses across 12.25" hole in carbonates formations. The top section was cased with 18 5/8" and 13 3/8" casings. Across the interval of interest, drill pipe was inside the borehole filled with water-based mud and the Chorus and Cascade logging tools (SNL-HPT) were conveyed by a slickline located inside the drill pipe.
Improving Zonal Isolation and Cutting the Water Production with the Help of an Engineered Self-Healing Cementing System: A Case Study Review of the First Implementation of its Kind in Kuwait
Authors: Al-Khayyat Bader , Al-Mudhaf Meshari , Saffar Ali Hussein , Mitra Tarasankar , Monteiro Ken , Al-Safran Sarah , Gholoum Saleh , Al-Khaja Mohamed , Ali Jasim , Al-Rashed Fatemah , Alotaibi Mohammad , Almunayes Fahad 
Published: March 2022

Abstract
In one of the prolific fields in Kuwait, achieving zonal isolation posed a big challenge mainly due to setting the production liner shoe close to the oil-water-contact zone. Cement bond logs from the primary cementing jobs were not acceptable due to contamination from intruding water leading to a high water-cut in the produced oil. We review the first implementation of a self-sealing Cementing System in Kuwait to improve zonal isolation and cutting the water production.
A comprehensive pre-job study was executed to engineer a suitable cementing system containing a swellable elastomer for oil-water-cuts with proper test in Lab. A novel HPHT multi-function test cell apparatus and procedure were utilized to measure in-situ ability of fractured cement specimens to seal oil-water-flows under the given simulated downhole conditions. Shrinkage or expansion of the set cement was also verified under pressure and temperature with a continuous test method run over several days. Thorough lab tests and Computational Fluid Dynamics simulations were run to enable a fit-for-purpose and robust cement slurry design ensuring proper placement of the cementing system in the well.
This paper will describe how this cement was designed and engineered in laboratory. It will also describe how the set up was made simulating a crack in cement specimen and injecting water cut oil reacts and provides desired results.
A calculated cement engineering approach was adopted to ensure better cement slurry placement and reduce the chances of slurry contamination. The test conditions were staged to replicate the most appropriate downhole conditions of pressure, temperature and simulated micro channel in the cement sheath. After the successful implementation of the self-sealing cementing system along the 7-in production liner in 2 wells, the corresponding cement bond log images showed hydraulic isolation and the production data from the wells indicated a reduction of nearly 50% in the water cut thus allowing a favorable oil production.
This technology is applied in other wells of this field and other fields also with good results. This is being continued to use in critical wells.
Seismic Models of the Barik Reservoir
Authors: Gangopadhyay Abhijit , Kumar Dhananjay 
Published: March 2022

Abstract
Seismic modeled responses for known geological models, often using well logs, help interpret field seismic data for reservoir characterization. The seismic response of the Barik reservoir is investigated based on its properties as revealed by well logs. The porous Middle Barik manifests itself on the synthetic seismic data within the relevant bandwidth of the available seismic. In the Extended Elastic Impedance domain, chi projections of +30 and -60 appear to separate sand from shale lithology, and relatively high from low porosity in the Barik reservoir, respectively. Various models of the Barik reservoir are also built. These include ones with varying rock properties, thicknesses, and porosity. In the models with varying rock properties, the AVO signature of the Barik sand changes from class IV when the change in Vp/Vs ratio at the interface is weak, to class II or III in other cases. Effects of changes in fluid type are negligible, although a gas charged Barik sand exhibit strong AVO intercept and gradient amplitudes. The AVO behavior of the Barik sand is also dependent on its thickness. A thicker Barik sand shows class IV AVO with a strong negative intercept and positive gradient, whereas one that is half as thick displays class II AVO with a weak negative intercept and negative gradient. The porosity of the Barik sand influences its AVO behavior. The insitu and relatively low porosity Barik sand show class IV AVO with a sharply decreasing gradient for tighter Barik, whereas a higher porosity Barik sand showed a stronger gradient. Lastly, the frequency-dependent AVO signature of the Barik reservoir is investigated. The analysis revealed that the fluid signature is indistinguishable at 20 Hz but may be distinguished at 30 Hz.
Active Learning for Well Control Optimization with Surrogate Models
Authors: Yu Junjie , Jafarpour Behnam 
Published: March 2022

SummaryOptimization of well controls in waterflooding operations has been established as an effective strategy to increase oil recovery efficiency and to reduce operating costs. Optimization problems, however, entail hundreds of full-scale reservoir simulation runs, which can be computationally expensive and impractical for field-scale applications. Fit-for-purpose surrogate models present more efficient alternatives that can be deployed for faster implementation and to enable real-time applications. In recent years, machine learning (ML)-based surrogate models have gained traction in building efficient proxy models to facilitate reservoir engineering and management workflows. For high-dimensional control variables that are frequently encountered in life cycle optimization, gradient-based local search methods have proven to be the optimization algorithms of choice, especially when adjoint models are available to provide the required gradient information in a computationally efficient manner. The use of local search optimization techniques implies that the surrogate models should be locally accurate and adapted to the optimization path that is traversed during the iterations. The adaptation can be accomplished through active learning, where the training of the surrogate model is performed online (throughout the iterations) and tied to the optimization iterations. This paper presents an active learning framework that is tuned to the local search nature of the optimization problem by updating an initially trained surrogate model based on new samples that are generated during the optimization iterations. Specifically, at each iteration, the full reservoir simulation model is performed to evaluate the true objective function and provide the new simulated data to update the surrogate model, thereby enhancing its local prediction accuracy. As the optimization progresses, older samples that become less relevant to the solution at the current iteration are dropped to preserve the local nature of the surrogate model. Various aspects of designing an active learning-based proxy model for well control optimization are discussed and the framework is applied to waterflooding problems to demonstrate its efficiency and superior performance compared to the traditional offline training approach.
Comprehensive Meteorological and Hydrological Drought Risks Under Changing Environment on the Wanquan River Basin, Southern China
Authors: Li Dan , Liu Bingjun , Ye Changqing 
Published: March 2022

Abstract
Drought is one of the most frequent and devastating natural disasters. Based on future climate scenarios and land use/land cover (LULC) patterns, this study employed the copula framework to calculate the probabilities of meteorological drought risk based on downscaled data as well as hydrological drought risks based on SWAT model simulation data for the next 30 years (2021-2050) in the Wanquan River Basin (WRB), and meanwhile, the relationship between hydrological and meteorological droughts was revealed by correlation analysis and cross wavelet transform (XWT). The results are as follows: (1) In the next 30 years, the risk of intra-seasonal meteorological drought (short-term drought) in the WRB is high at a probability of 40%-70%, while the risk of inter-seasonal meteorological drought is relatively small at a probability of close to 30%; (2) Compared with meteorological drought, the risk of intra-seasonal hydrological drought is small, but the probability of inter-seasonal hydrological drought (medium or long term drought) is 30%-50%, and the risk of hydrological drought in the upstream is greater than that in the downstream; (3) The future meteorological and hydrological droughts in the WRB are significantly and positively correlated, and that hydrological drought lags behind meteorological drought.