bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reduced Polymer Loaded Fracturing Fluid For Extreme Temperature Proppant Fracturing
Authors: Karadkar Prasad , Malik Ataur , Alabdrabalnabi Mohammed , Liang Feng 
Published: March 2023

AbstractGuar gum and its derivatives based fracturing fluids are most commonly used in hydraulic fracturing. For high temperature wells, guar-based fracturing fluids need to be formulated with higher polymer loading and at high pH that leaves insoluble residue and tendency to form scales with divalent ions. In this paper, newly developed reduced polymer loaded fracturing fluids based acrylamide polymer was deployed from lab developments to field implementation. A thermally stable acrylamide-based polymer with a reduced polymer loading of 30-40% less than guar-based fracturing fluid was considered to minimize formation damage concerns. The crosslinked fracturing fluid viscosity was optimized at 340°F, bottomhole static temperature, and 315, 290, 265 and 240°F cooldown temperatures using a high pressure high temperature (HPHT) rheometer. For successful field deployment, a novel reduced polymer fracturing fluid was evaluated in the following sequence: chemical management, quality control, optimization of fracturing fluid formulations with field water, field mixing procedure, on-site QA/QC, data frac analysis and execution of main treatment.This paper presents rheological studies of reduced polymer loaded fracturing fluids at bottom hole static temperature (BHST) and cool down temperatures of selected well candidates that demonstrate the superior thermal stability of this novel fracturing fluid. With a polymer loading of 35 lb/1000 gal, the fluid viscosity stayed above 300 cP at 100 1/s shear rate for 60 min at 340°F. The fracturing fluid formulations were optimized using both live and encapsulated breakers using high pressure and high temperature rheometer. Due to the fast hydration of the base polymer, the linear gel was mixed on-the-flying during the main fracturing treatment. The main fracturing treatment was successfully executed with a 40 barrels per minute (bbl/min) pumping rate with increased proppant concentration up to 4.5 pounds per gallon (ppa) using 40/70 HSP (high strength proppant) proppant. The fracturing fluid system based on the novel acrylamide copolymer offers advantages over guar-based fracturing fluid such as low polymer loading, excellent high temperature stability and less formation damage. This paper presents a systematic approach and lessons learnt during novel fracturing fluid deployment.
Novel Techniques to Prevent Wax Deposition During Hydraulic Fracturing of Low-Temperature Waxy Oil Reservoirs
Authors: Dadwani Aashish Dheeraj , Shah Maunish Sanjay 
Published: March 2023

AbstractHydraulic fracturing is the key well-stimulation technique to recover oil and gas from tight and unconventional reservoirs. The primary challenge encountered during hydraulic fracturing of the shallow waxy oil reservoir is cooling the reservoir while pumping low-temperature fracturing fluid, resulting in wax precipitation. Heating the fracturing fluid at the surface and blending water-dispersed paraffin inhibitor with fracturing fluid are the two techniques that prevent wax precipitation when the reservoir temperature decreases below the wax appearance temperature. This paper will suggest the best suitable technique for given reservoir conditions. When the formation temperature is cooled below the cloud point temperature, the paraffin precipitates and deposits in the reservoir pores causing formation damage. It is therefore suggested to maintain wellhead temperature above the wax appearance temperature of crude oil in the reservoir.An adequate concentration of viscosities would be selected to maintain desired viscosity at field conditions by identifying the suitable rheological model for propane placement in the reservoir. This would also suggest modification in infrastructure and formulation of cross-linked gel for the treatment. The paper would discuss the challenges faced when this method is upscaled at the field scale. This paper would also investigate a novel approach by incorporating insoluble paraffin inhibitors into a micro-dispersion system dispersible in water. Hydrofracturing fluid follows Herschel Buckley’s rheological model, which is a modification of the power law model. On increasing guar gum concentration by 1.5 gm/liter (50 lb/1000gal to 62 lb/1000gal), the average change in apparent viscosity is observed to be 14-20 cP depending on temperature. If we need to heat the fracturing fluid at 70°C, the concentration of guar gum needs to be increased. At 34°C, the apparent viscosity of standard hydro-fracturing is observed to be around 41 cP and at 68°C, viscosity decreases to 28 cP. After increasing the guar gum concentration by quantity 1.5 gm/liter, we observe that viscosity at 68°C becomes around 44 cP. The optimum concentration of guar gum needed to maintain viscosity is around 7 gm/liter (58.4 lbm/1000 gal). Hence it should be increased by about 16.67%.From the study of wax appearance temperature at the laboratory scale, the impact of water-dispersible paraffin inhibitors on paraffin control, oil quality, water quality, fracturing fluid compatibility, and production rates are evaluated. It is observed that production rates decline even after the hydraulic fracturing of the well, as paraffin damage reduces the formation's permeability. Thus, heated fracturing fluid and micro-dispersed colloidal paraffin inhibitors are the visionary methods to inhibit wax formation at the reservoir scale. It can be salubrious for the operators in stimulating +the reservoirs.
Productivity and Cost Comparison Between Radial-Borehole Fracturing and Horizontal Well Fracturing in Shale Oil Reservoir
Authors: Dai Jiacheng , Zheng Zeyu , Wang Tianyu , Li Gensheng 
Published: March 2023

AbstractGiven the abundant reserves, shale oil resource has great potential for future utilization. However, shale formation is often characterized by complex geological structures and developed stratification, which greatly restricts the formation stimulation performance of volumetric fracturing along the vertical direction in horizontal well and therefore raises development costs. To address such issues, a new method that utilizes radial-borehole fracturing based on vertical well is proposed to extract shale oil. This paper describes the fracturing network under radial borehole fracturing. A numerical model that considers shale formation, hydraulic fractures, and the wellbore is built to predict the productivity of radial-borehole fracturing and horizontal well fracturing. Moreover, a simplified cost evaluation model is built, respectively.Furthermore, this paper analyzes the influence of different well patterns, fracture heights, and Kv/Kh ratios on radial-borehole well productivity and compares the cost-effectiveness of a radial-borehole fractured well and horizontal well fracturing. Results indicate that radial-borehole fracturing is capable of eliminating the constraints of fracture height and thereby improving stimulation performance; more radial boreholes and main wells result in more oil production; in addition, as the fracture height decreases, the ratio Kv/Kh is closer to 0, it is more recommended to use radial borehole fracturing. A case study of Eagleford shale oil reservoir is herein carried out: The 9-vertical well, 3-layer, 4-lateral radial borehole fracturing brings the same oil production as the 3-horizontal well multistage fracturing (open hole completed) does, while the former costs 0.36 M$ less of the latter. Using radial borehole fracturing method to develop shale oil is proposed in this paper. The results can provide new insight into the effective development of shale oil resources at low cost.
Experimental Investigation of Asphaltene Deposition Remediation in Northern Iraqi Fields Using Green Metal Oxide Nanofluids/chemicals as Dispersants
Authors: Khidhir Dana Mohammad , Sidiq Hiwa 
Published: March 2023

AbstractPrecipitation of asphaltene is a significant technological Hurdle for the petroleum industry. There are several processes utilized to eliminate or stop the precipitation of asphaltene, while the applications of asphaltene inhibitors give the most efficient and cost-effective method of treating deposits. This study examined the practical effects of Asphaltenes were studied using inhibitors (ASFIN and ZnO NFs) also the remediation of asphaltene in dynamic conditions in terms of Pressure, Temperature and inhibitor concentration. An asphaltene precipitation loop was designed to mimic the real production scenarios in field conditions. It was found that nanofluids outperformed typical chemicals used in asphaltene remediation by a significant margin. Results of this experiment were then tested by UV-vis spectrophotometer which showed significant adsorption of asphaltene by nano particles.
Foam Formulation Development and Pilot Application in Low-Permeability Reservoirs
Authors: Zou Xinyuan , Luo Wenli , Wang Zhengbo , Jiang Zhibin , Han Xu , Chang Zhidong 
Published: March 2023

AbstractFoam flooding has been widely studied and implemented in recent years to alleviate reservoir heterogeneity and increase oil recovery. Previously, foam flooding was employed for conformance control and improving sweep efficiency, and little attention was paid to displacement efficiency. Thus, foam flooding usually had a poor ability to trip off oil film. Moreover, the effectiveness of many of the foam pilots lasted only a few months, and, in some cases, only a few weeks, which limited the long-term development of foam in field applications as the time to maximize effectiveness was too short. In this paper, a foam pilot selection, formulation design, and N2 foam pilot implementation are presented towards providing an effective method for transforming the development mode after water flooding in low-permeability reservoirs.Two well groups (two injection wells and 17 production wells) were screened as candidates for the N2 foam pilot. Laboratory investigations included bulk foam screening, imbibition recovery, and natural core flooding tests. One formulation of eight tested (No. 6) showed excellent foam properties as well as a strong ability to strip oil from sand, and natural core scale work under reservoir conditions resulted in a total recovery of 66.92%, with an incremental recovery of 25.25% by N2 foam after water flooding.The pilot was deployed using a new injection strategy of a surfactant alternating gas method in which surfactant was injected into water for 1 d at a normal injection rate followed by N2 injection for 1 d at a large injection rate. A positive response was observed after injection for approximately 1.5 months, daily oil production climbed sharply, and water cut also decreased after processing of 1% of pore volume with foam solution. Moreover, production was sustained for 18 months after foam injection, which resulted in approximately 4375 t of incremental oil. The foam pilot was successful in addressing the challenges associated with dominant channel and low displacement efficiency of water flooding in low permeability sand reservoirs.
Uplifting Engineer's Competency for Unlocking Asset Value in The Energy Transition Era: Cross-Organizational Knowledge Sharing Management System
Authors: Yonebayashi Hideharu , Matsubuchi Hitoshi , Shoukry Medhat , Al Marzouqi Adel Abdul Rahman , Abdesalam Elmansouri Mohamed Elhassan , Al Remeithi Hamda Mohamed , Eshbair Ibrahim , Kawahara Hiroshi 
Published: March 2023

AbstractE&P technology in the energy transition era is more rapidly progressed because of various innovations from other industries, digital transformation, and broader knowledge sharing from other industrial sectors. Therefore, skills of engineers in frontline: namely employees in operating companies (OPCO) will have deeper impacts on project values. To uplift their technical competency, this paper discussed how to maximize leaning/training program values and provide the opportunities from long term perspective as a part of holistic talent development management system. In-house leaning/training courses and/or commercial training programs, which have been commonly provided, will not be sufficient for pursuing competitive level in future as long as the knowledge sharing opportunities are limited to in-house or generalized contents for maximum numbers of demand. Thus, the opportunities are unlimited by incorporating additional seminar/training courses, offered from stakeholders: an asset lead in particular, into the OPCO's youth development plan (YDP) to be more effectively provided from many viewpoints of participant adequateness (discipline, technical interest, maximum number of attendees), annual schedule planning, and interactive feedback to improve the programs.INPEX/JODCO, an asset lead international oil company (IOC) responsibly developing concession of the Abu Dhabi offshore field, has been operating domestic oil/gas fields and an abroad giant LNG project, furthermore, managing various non-operating projects all over the world. From all the projects, therefore, many types of knowledge-sharing seeds have been gathered to prepare seminar/training contents and lecturers via the IOC's corporate technical division while taking OPCO's demands into account. Dozens of programs have been offered since 2018 for various disciplines. One of them: the JODCO Drilling Academy (JDA), providing total 61 courses as of November 2022 covering major drilling & completion related topics is recognized as the most successful contribution. A cycle from seminar planning, execution, feedbacks, and updating are established to work as a cross-collaborative talent development management system.
Deliberate Selection of Wellbore Flow Profiling Technology
Authors: Tveritnev Alexey , Boyd Douglas Alexander , Abdel Aziz Ahmed 
Published: March 2023

AbstractWellbore production / injection flow profiling provides key information for reservoir production and hydrocarbon recovery management. To collect wellbore liquid / gas flow profile data, ADNOC's Onshore Engineers utilise three proven technologies; Production Logging Tools (PLT), Fiber Optical Downhole Temperature Sensors (DTS) and Inflow Chemical Tracers (ICT) placed on the completion. Each technology utilises different physics and has unique implementation requirements. The optimum monitoring technology is selected at the well planning stage with considerations to well design, completion type, fluid type, well purpose (injector or producer), economics, technology reliability, installation / data collection operational considerations, expected lifetime, interpretation confidence, field maturity and field monitoring strategy. Each monitoring option might be applicable under certain operational and well construction constraints, and provide results within required uncertainties. This paper shares ADNOC Onshore's guidelines for the selection of the most appropriate flow monitoring technology for its oil and gas reservoirs developed primarily with horizontal wells and water injection for pressure support.
Intelligent Wireline Formation Tester Evaluation of Low-Permeability and Low-Resistivity-Contrast Formation with Detailed Digital Planning.
Authors: Guan Lijun , Wang Xiannan , Wang Jian , Bei Gao , Gisolf Adriaan , Fan Zhaoya , Partouche Ashers , Kristensen Morten , Li Shiju , Chen Li , Chen Jichao 
Published: March 2023

AbstractExploration and development drilling in offshore China is extending to Paleogene formations that are characterized by low-resistivity-contrast and low-permeability rocks. These formations have become a focus for increasing reserves and production. During exploration activities, these low-resistivity, low-formation-contrast formations have been critical and challenging for formation evaluation because the geological structure and lithology are more complex than in previously discovered fields. Differentiating hydrocarbon from water using petrophysical interpretation has a large uncertainty in these formations. Confirming the fluid type using conventional formation testing technology has been extremely challenging because the produced fluid is mainly mud filtrate, which is of no use for fluid confirmation.The dual-flowline architecture of the intelligent formation testing platform (IFT) is designed to systematically address shortcomings of legacy technology, enabling focused sampling in the tightest conventional formations. Specialized digital planning of the numerical flow models by adding a brine tracking facility and enumeration initialization was performed to (a) compare and benchmark the cleanup performance of conventional radial 3D probe and new focus radial probe; (b) simulate multiple scenarios including hydrocarbon-water transition to understand the salinity changes while pumping in various water saturation circumstance and optimize operational planning by quantifying cleanup time uncertainties even in two-phase fluid reservoir; and (c) history match the sampling drawdown, flow rate, and salinity change with actual sampling data and provide real-time answers to help accelerate the decision-making cycle.This dedicated design resulted in increased efficiency in water sampling compared to previous testing done by the operator. Whereas previous gas-water transition zone sampling was challenging because high water-based mud filtrate fractions masked the presence of formation water and formation hydrocarbon, the focused radial probe, combined with state-of-the-art resistivity measurements and prejob modeling of salinity change, allowed identification of gas and the measurement of formation water resistivity in a multiphase flow environment. The formation testing of these low-resistivity-contrast and low-permeability formations enabled acquisition of a 2% contaminated formation water sample in 140 minutes with formation mobility of 1 md/cP. The gas-water zone was confirmed from a dual-flowline resistivity measurement and a hydrocarbon show in mobility of 1.4 md/cP. The intelligent wireline formation testing platform enabled high-performance and efficient collection and identification of formation water and gas in a low-mobility low-resistivity-low-contrast formation.
Automated Hyperparameter Optimization of Convolutional Neural Network (CNN) for First-Break (FB) Arrival Picking
Authors: Ayub Mohammed , Kaka SanLinn Ismail 
Published: March 2023

AbstractThe Convolutional Neural Network (CNN) has been used successfully to enhance the First-break (FB) automated arrival picking of seismic data. Determining an optimized FB model is challenging as it needs to consider several hyperparameters (HPs) combinations. Tuning the most important HPs manually is infeasible because of a higher number of HP combinations to be tested. Three state-of-the-art automated hyperparameter optimization (HPO) techniques are applied to a CNN model for robust FB arrival picking classification. A CNN model with 4 convolutional (Conv) layers followed by one fully connected (FC) and one output layer is designed to classify the seismic event as FB or non-FB. To control overfitting, dropout (DO), batch normalization are used after every two Conv layers, in addition to only the DO layer after FC. The number and size of kernels, DO rate, Learning rate (Lr), and several neurons in the FC layer are fine-tuned using random search, Bayesian, and Hyper Band HPO techniques. The findings are experimentally evaluated and compared in terms of four performance metrics with respect to classification performance.The five hyperparameters mentioned above are fine-tuned in 13 search spaces for each of the three HPO techniques. From experimental results, applying random search HPO to CNN yields the best accuracy and F1-score of 96.26%, with the best HP combination of 16, 16, 32, and 64 for numbers of kernels in four Conv layers respectively; 2, 2, 2, 5 for the size of kernels in each Conv layer; 0, 0.45, 0.25 for DO rate in each of DO layers; 240 for numbers of neurons in FC layer; and 0.000675 for Lr. In terms of loss on test data, the above combination of HP gives the lowest test loss of 0.1191 among all techniques, making it a robust model. This model outperforms all the other models in terms of precision (96.27%) and recall. Moreover, all HPO models outperformed the baseline in terms of all metrics. The use of DO after Conv layers and FC layers is highly recommended. Moreover, the use of kernel size relatively smaller (i.e. 2) produces the best classification performance. According to the best HP combination results, there is also no harm to use a relatively higher number of neurons in the FC layer than the Conv layer in FB arrival picking classification. The optimal values of Lr range from 0.0001 to 0.000675 depending on the HPO techniques. The model developed in this study improves the accuracy of the auto-picking of FB seismic data and it is anticipated our model to be used more widely in future studies in the processing of seismic data.
New Engineering Approach Using State of the Art RSS to Overcome Complex Colombian Foothills and Improving Drilling
Authors: Hernandez Juan Manuel , Gomez Jose Luis , Lopez Alexander , Garzon Fredy , Celis Manuel , Montes Daniel , Gamba Ivan 
Published: March 2023

AbstractDrilling in Colombian foothills have been a big challenge since BP drilled on this area in 1987, currently operating by Ecopetrol S.A foothill implementing innovative well design and new technologies. This basin has been characterized by its complex geological conditions, structure full of faults and high stresses that make drilling operation a big challenge.New well construction engineering based on thorough offset wells and NPT events analysis in addition to the implementation of lessons learned from previous wells in the area, combined with state-of-the-art rotary steerable system have changed the way of drilling in Colombian foothills field overcoming all the challenges faced in the past.To achieve this success, the following approach was followed: Concatenate well profile to balance dogleg severity to minimize tortuosity to allow running the casing smoothlyInnovative well design to achieve exploration objectives in Cupiagua XD45, a well drilled by Ecopetrol S.A. in 2022.BHA optimization including state-of-the-art rotary steerable system to enhance the drilling performance.Transient finite element simulation for 12 ¼" × 14 ¾" section to determine optimum rotary steerable BHA and underreamer cutting structure configuration to achieve smooth drilling condition and borehole quality.This integrated approach allowed to: Optimize well trajectory design process achieving lower and concatenated dogleg severities driven by formation dips bedding to avoid wellbore instability problemsOptimum BHA design and stabilization to minimize stuck probability and assure an optimal BHA dynamic while drilling the wellMinimize borehole tortuosity using last generation of RSS system to achieve smooth borehole quality enhancing tripping, drilling, and running the surface casing and intermediate liner, improve drilling, tripping and casing run performance.Simulation and technical analysis to choose the proper bit profile and design correct underreamer’s cutters to run on 12 ¼" × 14 ¾" section to deliver good wellbore quality and allow smooth 11 ¾" × 11 7/8" liner.This new well construction engineering approach represent an effective solution to overcome Andean foothill challenges achieving optimum borehole quality and improving drilling performance in complex drilling environment by incorporating state-of-the-art RSS