bluuebunny/crossref_metadata_2025_split huggingface dataset:
Assessing Sustainability Strategies in the Oil and Gas Sector through the Sustainable Development Goals. A Case Study of a Multi-Stakeholder Innovation Ecosystem
Authors: Menéndez Jaime , Fernández Jorge , Araujo Andrés 
Published: February 2022

AbstractDeveloping effective sustainability strategies by oil and gas (O&G) companies requires that they embrace the global call to incorporate the United Nations’ Sustainable Development Goals (SDGs) into their business strategies and operations. However, more attention is needed in the academic literature regarding the analysis of the linkage between O&G companies and the SDGs. A previous study by the authors proposed an analysis process in order to assess sustainability strategies in the O&G sector, based on the combination of two sources of information provided by relevant international organizations in the energy field. This initial research focused on a small number of SDGs, which may not reflect the complexity of the approach to sustainability by an O&G company. Therefore, an extension of the analysis is introduced in this paper following a research with two stages. The first stage is based on case study methodology (taking a refinery in the Basque Country, in Northern Spain). This yields a qualitative identification of different avenues that the O&G company under study can follow to contribute to targeted SDGs with its own technological and industrial resources and current research and innovation projects. Building on this, the second stage of this line of research focuses on identifying which business relationships are the result of the activities and projects that contribute to SDGs. As a whole, the universe of business and non-business relationships constitute a growing multi-stakeholder innovation ecosystem on which the company relies to achieve its sustainability objectives. This innovation network around the refinery's operations encompasses a variety of stakeholders (companies, technology and research centers, universities and others) working on innovative projects related to hydrogen and synthetic fuels production, circular economy, electric vehicles, energy storage, renewable energy communities or digitalization, among other technologies and energy carriers. This ecosystem is supported by a web of public-private cooperation schemes at different government levels. The outcome of this approach to innovation reflects how, by adopting a multi-energy strategy, the analyzed company can act as a catalyst for innovation spillovers and synergies in the whole Basque Country region, which has implications that go beyond energy and climate issues.
Novel Internal Coating System for High Concentration H2S Environments
Authors: Lauer Robert 
Published: February 2022

Abstract
Traditional internal coating systems relied on phenolic, novolac, epoxy or blended resin systems. These tended to provide good barrier properties in the environments they were developed for, but as with all materials, there were limitations. One of those limitations that had to be overcome during the development and application process was that during the curing process, they can tend to shrink, so greater surface preparation processes must be followed to ensure that the system adhesion far outweighs the residual stress in the coating system. In sweet applications, this residual stress offers little to no effect on a properly applied coating system provided its design parameters are not exceeded. In the presence of higher concentrations of hydrogen sulfide, there can be a negative effect on the adhesion of most of these resin type coating systems allowing the residual stress to play a role in blistering and disbondment. A new and novel resin system has been developed that does not shrink during the curing process and can be applied as a primer-less system. Coatings developed with this new resin, benzoxazine, allows the coating system to maintain good adhesion and barrier properties in H2S concentrations two to three times greater than the current leading H2S resistant coating systems on the market today. This paper is the second in a series on the development of this product into a coating solution. Further laboratory refinement will be discussed leading to the next phase of the roll-out which will be field trials.
Evaluation of Biot's Coefficient Using Sonic Logs and Elastic Moduli Minimization
Authors: Vorobiev Sergey , Vorobyev Vladimir , Lukin Sergey , Zhigulskiy Svetlana , Chebyshev Igor 
Published: February 2022

Abstract
Biot's coefficient is one of the key parameters in estimating effective stresses, leading to understanding of the three stresses spatial distribution, namely vertical, minimum and maximum horizontal. Ultimately, these stresses shape up the behavior of a geomechanics model (either in 3D or in 1D). Thus, the robustness of any geomechanics model significantly depends on the precision of Biot's coefficient estimation. The proposed technique allows evaluating isotropic and anisotropic Biot's coefficients based on the log responses independent of the geological environment.
The methodology is based on elastic moduli-minimization. In isotropic case, Bulk rock frame and Bulk rock grain moduli minimization produce the best fit to the measured Density, DTP and DTS. Then, isotropic Biot's coefficient can be computed directly. In the case of anisotropy, additional control on lamination is required. This can be achieved by comparing estimated laminated and dispersed clay volumes based on the anisotropic rock-physics model and derived from the Thomas-Stieber plot or any alternative lamination analysis technique. Anisotropy modeling allows to produce five independent VTI elastic moduli and as a result to compute anisotropic Biot's coefficient.
The methodology has been tested in several fields: clastic (Western Siberia, Norwegian offshore, Argentina unconventional) and carbonates (Brazil, Middle East, North Sea chalks). It produces reliable results in all cases. This study shows good agreement of the Biot's coefficient computed from the proposed methodology with measurements of core-based Biot's coefficients. In practice, core-based Biot's coefficient measurements are rarely available and quite often done on a few samples, taken in the reservoir section only. The proposed methodology allows reliable estimates of Biot's coefficient for the entire wellbore section, where density and sonic logs are available. It utilizes a minimization technique instead of using geomechanics correlations. Thus, it is applicable for any rocks and geological settings and is not bounded to the area or formation compared to correlations specific to the particular formation.
The novelty of the method is in the process of elastic-moduli minimization based on logs and allows direct extraction of the Biot's coefficient. Previous works were either concentrating on principles of the laboratory Biot's coefficient measurements or focusing on the correlations derived from core tests. Correlation derivation requires a significant number of core tests conducted for the same geological settings. However, the proposed methodology requires a few core samples for Q.C. purposes only.
Pressure Transient Analysis in Shale Wells with Heterogeneous Fractures by Using a Deep Learning Based Surrogate Model
Authors: Chen Zhiming , Dong Peng , Wang Tianyi , Cai Mingjin , Tian Yong , Zhang Jiali 
Published: February 2022

Abstract
With hydraulic fracturing technology, manmade fractures can be generated around the shale-gas wells. After hydraulic fracturing at each stage, many wells in shale reservoirs have the "shut-in" process, which providing many precious data for parameter estimation. But, owing to intricate geological and engineering factors, the fractures in reservoirs are asymmetric and heterogeneous, which brings a great challenge for fracture estimation.
To improve this situation, coupling the deep learning (DL) approach and field practices, we established a surrogate model for non-uniform fractures at one stage based on deep Bi-directional LSTM model. First, a well testing model containing three distinct flow regions is developed, namely (1) heterogeneous hydraulic fractures, (2) the inner region affected by hydraulic fracturing, and (3) the outer region without stimulation. Laplace transformation method are used for model solutions. Then, with the model solutions, a surrogate model based on deep bidirectional LSTM is built for improve computational efficiency. The results show that the model can effectively reduce the early prediction error of pressure derivative, and the average relative prediction error is 1.67%. Finally, model verification was shown by comparing with the results from traditional well testing model. The results show that the calculation speed of the surrogate model is three orders of magnitude higher than that of the well test model, which helps to efficiently evaluate the fracture parameter in complex fracture system generated by large-scale fracturing treatments in shale reservoirs.
Experimental Study of Shape Memory Sand Control Screen
Authors: Ai Shuang , Duan Youzhi , Chen Yashu , Gao Chen , Rached Rached 
Published: February 2022

Abstract
Shape memory sand control screen completion based on shape memory polymer not only has the advantages of simple process and easy to run in hole, like independent screen, but also can achieve the sand management effect of gravel filling. Therefore, shape memory sand control screen has wide application prospects. However, since the shape memory material is temperature-sensitive, a large number of laboratory experiments are needed to evaluate its expansion, seepage and sand retaining capabilities, as well as optimize the polymer system and screen structure.
A performance evaluation experiment system for full-size shape memory screen prototype was developed. The device can describe the parameters of the shape memory screen during the expansion process and after expansion in real time and quantitatively, such as permeability, outer diameter and residual stress. The expansion behavior of screen prototype is controlled by step heating the passing through fluid to simulate the screen run in hole operation. 60 sets of experiments were carried out using the device. The expansion performance, seepage performance and sand control performance of shape memory screens were evaluated. Shape memory polymer formulation and screen structure are also optimized.
The research shows that the optimized shape memory sand control screen densely filled annulus and effectively supports the wellbore after expansion. The permeability of the expanded screen can be up to 35µm2, the displacement pressure difference can be less than 1kPa, and the sand control precision can be up to 0.061mm. Therefore, shape memory sand control screen can be used for sand control completion of oil and gas wells with limited well site conditions such as long horizontal wells, complex wells and offshore wells.
This paper presents an experiment device to evaluate the performance of shape memory screen, the dynamic expansion behavior is described during the expansion process and after expansion in real time and quantitatively.
Adding a New Lease of Life to a Sub-Hydrostatic Hydraulically Fractured Gas Well Using Coiled Tubing with Real-Time Telemetry
Authors: Pooniwala Shahvir , Brohi Imad , Waheed Arshad , Khan Abdul Muqtadir , Hamidon Zahaezuani Rafiq 
Published: February 2022

Abstract
Post-fracturing cleanup and production revival in sub-hydrostatic wells can be challenging. The complexity is amplified in sub-hydrostatic multistage horizontal wells because, by the time the fracturing treatment is concluded, the gas phase of the energized fracturing fluids used during the initial stages of the fracturing treatment dissipates. In the subject sub-hydrostatic well, coiled tubing (CT) with a real-time telemetry system was utilized over a standard nitrogen lifting intervention utilizing conventional CT to revive a hydraulically fractured well due to its capabilities to enable real-time decisions using live bottom-hole data.
Acid fracturing using an energized fluid treatment was conducted in the subject gas well completed with a multistage open-hole completion system using isolation packers and sleeves. As the subject well was sub-hydrostatic, it was decided to utilize the CT with real-time telemetry system to gain value from its associated downhole parameters during the cleanup phase to alleviate the chances of successfully lifting the well.
The well was placed in an area with prolific offset producers; hence, there were high production expectations from this well. A review of the well indicated a decreasing trend of reservoir pressure from heel to toe of the lateral, possibly contributing to lower stresses and potential crossflow between stages. Hence, the diverter concentrations and volumes per stage and nitrogen rates were maximized for each new fracturing stage to attempt to create new fractures. Considering the challenges with the well, it was essential that the N2 lifting operation parameters should be optimized to enhance drawdown. It was decided to utilize CT with a real-time telemetry system to control drawdown parameters better and maximize the possibility of success. Real-time downhole pressure measurements were utilized to accurately identify the fluid gradient followed by real-time evaluation and monitoring of the well behavior during N2 lifting operations. The real-time downhole data collected enabled on-the-fly intervention optimization leading to transforming the well into an economic producer.
The integrated post-treatment analysis workflow provided a robust insight into fracture treatment design and evaluation, reservoir imbibition perspective, openhole completion practices, and the importance of real-time telemetry for challenging interventions. The lessons learned that are presented in this paper could act as a guide to contribute to operational efficiency enhancements and cost savings in other projects.
Case Study: Lessons Learned in Attempting to Restore New Well Productivity Via Solid Propellant Technology and Dynamic Underbalance Stimulation
Authors: Dasuki Nurul Ain , Reekhi Gurveen Singh , Bakar Hasmizah , Tunku Abdul Muthalib Tunku Indra 
Published: February 2022

Abstract
In Field A, recently drilled wells D6, D7 and D8 penetrated at reservoir of good quality sands. However, the production rate declined rapidly within a year after wells kicked off. In an effort to restore new wells productivity, solid propellant technology stimulation and dynamic underbalance stimulation were evaluated for their effectiveness in permeability improvement. The candidates for solid propellant technology and dynamic underbalance stimulation were selected based on a screening workflow. Pressure data was retrieved from pressure downhole gauge to confirm skin buildup post production. The sources of production impairment were then investigated from laboratory analysis of core sample. While waiting for the results of laboratory analysis, solid propellant technology and dynamic underbalance stimulation were applied as quick solutions due relatively cheaper cost than chemical stimulation. Solid propellant technology was chosen for Well D8 whereas dynamic underbalance stimulation was selected for Well D6 and D7. Post solid propellant technology at Well D8, tubing head pressure and production rate slightly increased and sustained. On the other hand, dynamic underbalance stimulation at Well D6 and D7 showed positive results as tubing head pressure and production rates were improved. Unfortunately, production gain from dynamic underbalance at Well D7 only lived for a month before seizing to flow. The implementation of solid propellant technology and dynamic underbalance stimulation were successful to improve production performance for a short period of time. Both stimulation strategies were deemed to be repeated and improved to bypass near wellbore damage for these wells. This paper presents on the challenges and lessons learned that will be applicable to oilfields which are having similar situation to improve well productivity via mechanical stimulation.
Data-Driven Model for Measuring Hydraulic Fracturing Efficiency by Utilizing the Real-Time Treatment Data
Authors: Zhukova Kseniia , Antonic Miroslav , Soleša Mišo , Camber Dragan 
Published: February 2022

Abstract
The paper presents a practical tool for hydraulic fracturing efficiency evaluation. The tool is based on a data-driven approach that helps in interpreting real-time data. Based on the hydraulic fracturing (HF) job monitoring, statistic metrics and key performance indicators (KPIs) are generated to be valuable input for further designs and identification of potential savings in operation.
Machine learning (ML) algorithms are proposed to reduce the tedious work of completion engineers by automatically classifying each treatment schedule's timestamp and assigning the stage label. For operation stages classification Support vector machines and neural networks algorithms are used. These models are trained and evaluated on real-time treatment datasets. After automatic stage recognition, relevant statistic parameters are calculated, enabling advanced data analytics. Detailed analysis of historical data allows to identify the areas for improvements and set new best practices.
The first research objective was to gather data from various companies and structure them under the same template to conserve the most critical information gained during the hydraulic fracturing job. Afterwards, the data are preprocessed and labelled by using signal processing routines that significantly decrease the labelling time. The labels or classes are used to define different stages that can be distinguished during the treatment. Finally, the goal is to decrease the necessary time for data labelling. Therefore, two multiclass classification models (Support Vector Machines (SVM) and Neural Network (NN)) are built and evaluated. Based on evaluation metrics, both models resulted in high accuracy and reliable results. However, the SVM model resulted in slightly higher accuracy and an F1 score. The key value of these models is that they provide a computational method to extract a pumping schedule from hydraulic fracturing time-series data automatically. Also, these models allow conducting post-job analysis and choosing the proper pump schedule for a future HF treatment based on previous experience. This past-job analysis could contribute to the effectiveness of future operations by utilizing the materials and fluids more efficiently.
Flow Pattern Recognition in a Rotating Centrifugal Pump via Inflection Characteristics of the Performance Curves
Authors: Li Yuanyuan , Zhu Jianjun , Cao Guangqiang , Zhang Yongxue , Lu Yingda , Lu Bo , Zhu Haiwen 
Published: February 2022

Abstract
Of significant importance to multiphase flow, the gas-liquid two-phase flow pattern is extremely difficult to characterize in centrifugal pumps, where the impeller rotates at high speeds shrouded by the steal-made nontransparent casing. How to observe the flow patterns inside the rotating impeller has drawn considerable attention. In this study, an indirect flow pattern recognition approach via inflection characteristics of H-Q performance curves in a centrifugal pump is proposed and verified by both experiments and numerical simulations. An acrylic-made transparent impeller was employed to conduct experimental testing and visualize the internal two-phase flow patterns by a high-speed camera. To better illustrate the two-phase flow structure, the three-dimensional (3D) numerical simulation was performed and compared with visualization experiments. The preliminary results reveal that the inflections on the pump's H-Q performance curves can be regarded as the flow pattern transition boundaries under various flow conditions.
Physical Testing of a High-Speed Helico-Axial Pump for High-GVF Operation
Authors: Ejim Chidirim Enoch , Xiao Jinjiang , Lee Woon Yung , Zabala Wilson Andres 
Published: February 2022

Abstract
High-speed rotordynamic pump operation for downhole or surface production is required and also beneficial to handle very high gas volume fraction (GVF) flows. Operating speeds of these pumps can be in excess of twice those of conventional pumps. This study presents results showing a high-speed helico-axial pump (HAP) can operate satisfactorily at intake GVFs up to 98%. The findings increase capabilities of field engineers and operators to boost and maximize production from high gas-content wells.
The HAP tested had a housing outer diameter of 4.00-inch and operated at a rotational speed of 6000 revolutions per minutes (RPM). Air and water were the test fluids with the water volume flow rate held constant while the air volume flow rate was varied. The liquid and gas volume flow rates varied from 63 to 143 barrels per day (BPD), and 549 to 3238 BPD, respectively. Intake pressures varied from 14 to 76 psig, with average inlet temperature of 18°C. The corresponding discharge pressures and temperatures were recorded for each test point and observed for stable pump operation.
The results showed that the HAP had stable operation during the tests for intake GVF range from 84% to 98%. Pump discharge pressures for this range of high intake GVF varied from 21 to 89 psig. The corresponding differential pressures across the HAP all had positive magnitudes indicating that at such high-speeds, the HAP was still able to add energy to the fluid even with the high gas content at intake. Analysis at fixed intake pressure with varying GVFs showed that the discharge-to-intake pressure ratio decreased with increasing intake GVF. For instance, at 33psig intake pressure, increasing the intake GVF from 84% to 94% decreased the discharge-to-intake pressure ratio from about 1.27 to 1.20, respectively. It was also observed that tightening the clearance between the impeller and diffuser of the HAP increased the discharge pressure compared to when the clearance was loose. Furthermore, ensuring the upstream flow is properly conditioned also improved the stable operation of the HAP. Overall and in conclusion, running a HAP at high speeds in addition to optimizing certain features of the HAP can result in stable pump operation and enhanced pressure boosting in high-GVF flows.
This study mainly highlights the importance of operating HAPs at high speeds of up to 6000 RPM. Tightening clearances between rotordynamic components as well as tailored inlet flow conditioning are also additional features that enhance pressure boosting. This architecture opens up opportunities for field operators, and engineering personnel to maximize hydrocarbon production from their very high-gas content field assets, thereby increasing the economic bottom-line for the stakeholders.