bluuebunny/crossref_metadata_2025_split huggingface dataset:
Proven Well Stabilization Technology for Trouble-Free Drilling and Cost Savings in Pressurized Permeable Formations
Authors: Quiroz Broca Genaro , Maldonado Reinaldo , Rockwood Jené 
Published: March 2023

Abstract
Case studies have shown the benefits of applying a unique wellbore stabilization technology to solve lost circulation events occurring in varying pressurize, permeable, and fragile formations. Leveraging this technology can increase successful drilling in geologically complex areas while avoiding conventional solutions that are both costly and and, in some cases, do not solve the causes of non-productive time.
A unique wellbore stabilization technology has been proven effective in offshore wells in areas that are known to present small vugs, natural fissures, formation failure, wellbore erosion, and the associated drilling problems of lost circulation, poor cementing quality, problems running pipe, etc. When compared with the cost and operational lack of success offered by conventional "solutions" versus the relative low-cost and operational successes of the unique wellbore stabilization technology, the choice is clear – where use is appropriate, the stabilization technology has provided a greater success rate and trouble-free drilling operations at a lower cost than traditional solutions.
The unique wellbore stabilization product is designed to address microfractures (as small as 3 µm) up to much larger fractures (3,000 µm). The product can be added to oil-based or water-based fluids at functional levels without adversely impacting the fluid rheology. Once in the drilling fluid, the stabilization product forms a pressure-sensitive layer on the formation wall to isolate the drilling fluid from the wellbore and stop fluid invasion that leads to formation failure, uncontrollable lost circulation, and well control issues. Once drilling is completed, the drop in pressure differential of the wellbore fluid allows the protective particles in the drilling fluid to lift off with the initiation of production. In the Campeche wells, one early study showed a 36% reduction in drilling time and 24% reduction in cost.
This paper discusses the various options explored and detail the technical analysis that preceded the application of the wellbore stability technology. Case studies are presented to illustrate the effectiveness of the fluid technology in drilling three wells which encountered variable pressure regimes, from the highly pressurized Paleocene at around 5,000 m to underlying low-pressure sandstones. These three wells and their offsets represent the successful application of this low-invasion technology in major drilling basins where lost circulation events would normally incur major operational expenses and non-productive time (NPT).
Combining Best-in-Class Surveying Measurements to Provide the Most Accurate Wellbore Position
Authors: ElGizawy Mahmoud , Lowdon Ross , Aklestad Darren , Strain Paul , Boyce Fraser 
Published: March 2023

Abstract
A survey program is designed for every well drilled to meet the well objective of penetrating the target reservoir and avoiding colliding with other offset wells. The selection of the wellbore survey tools within the survey program is limited in number and accuracy by the current surveying technologies available in the industry. This article demonstrates how a higher level of accuracy can be achieved to meet challenging well objectives when the accuracy of the most accurate wellbore surveying technology individually is not sufficient.
This highest level of wellbore positioning accuracy to date is achieved by combing two wellbore positions of the same wellbore trajectory. The first wellbore position is calculated using the latest technology of magnetic Measurement-While-Drilling (MWD) Definitive Dynamic Surveys (DDS). The accuracy of the MWD DDS has been enhanced by correcting potential error sources such as misalignment of the survey package from the borehole, drill-string magnetic interference and limited global geomagnetic reference and accelerometer sensor accuracy. Further, the MWD DDS inclination accuracy is improved using an independent inclination measurement from the Rotary Steerable System (RSS). Hence the first position is derived from magnetic MWD DDS after applying In-Field Referencing (IFR), Multi-Station Analysis (MSA), Bottom Hole Assembly (BHA) sag correction (SAG), and Dual-Inclination (DI) corrections. A Second wellbore position is calculated using the latest technology in Gyro-measurement-While-Drilling (GWD).
The results and comparisons of multiple runs are presented. The highest accuracy of wellbore positioning had been proven in successful case studies by penetrating a very small reservoir target on an extended reach well that was unfeasible using either the most accurate enhanced MWD DDS or the latest GWD technology. The presented case study shows how the wellbore objectives of penetrating the tight target reservoir had been confirmed by Logging-While-Drilling (LWD) images and interpretation of the subsurface team. This gave the highest accuracy of the wellbore position accuracy to date while drilling assured placing the well with higher confidence to maximize reservoir production without colliding with nearby offset wells.
In reservoir sections, the wellbore survey accuracy limits boreholes' lateral and true vertical depth spacing, constraining reservoir production. In the top and intermediate sections, wellbore survey accuracy limits how close the well can be drilled in the proximity of other offset wells. This directly impacts the complexity of the directional work and the cost per drilled foot. This technique unlocks the potential to improve the wellbore positioning accuracy significantly. It demonstrates the highest wellbore positioning accuracy achieved to date when compared to the latest magnetic MWD surveys after correcting all known errors compared to the GWD.
System Integration Test (SIT) of Technology Enabling Through-Tubing Rig-Less Plug and Abandonment
Authors: Kverneland Johan , Drevillon Pierre-Marie , Tomczak Daniel , Gardner Dave 
Published: March 2023

Abstract
A System Integration Test (SIT), designed to investigate the performance of technology enabling through-tubing rig-less plug and abandonment is described. A key objective of this SIT was to verify and de-risk tools and techniques prior to their potential deployment in an offshore target well.
A deepwater well, located offshore Brazil, was used as the basis for the design of the SIT program. The objective of the well operation was to permanently isolate the production tubing and the A-annulus in which a flatpack containing 2x chemical injection lines and 1x electrical line is present. To ensure the flatpack would not provide a leakage pathway it had to be cut into pieces prior to cementing the A-annulus.
A completion string mimicking the main features of the well was designed utilizing 10 ¾in. casing, 6-5/8in. tubing with a flatpack and a restriction created by the downhole safety valve (DHSV). The completion was installed inside a large diameter test well and thereafter the technologies to be verified were deployed using wireline and rigless coiled tubing interventions.
After installation of the test well completion, the performance of various technologies was investigated through the following operations:
Flatpack detection with four different e-line ultrasonic & electro-magnetic tools Flatpack ablation with custom designed oriented shaped charges utilizing two different gun designs run on wireline Through tubing cement placement utilizing a Perf, Wash & Cement technique deployed on coiled tubing Coiled tubing cement mill out using a motor, bit and underreamer able to pass the DHSV and remove the cement plug from the tubing Evaluation of the annular barrier quality using a cement bond logging tool Recovery of the well completion, keeping the A-annulus barrier intact for subsequent inspection at surface and comparison to the log results
The performance of state-of-the-art technologies that can enable rig-less through-tubing plug and abandonment (P&A) utilizing wireline and coiled tubing interventions have been investigated and de-risked through an SIT executed in a test well completion mimicking an actual offshore deepwater well.
A Unified Model for Shale Barriers
Authors: Aadnøy Bernt S. , Kristiansen Tron G. , Belayneh Mesfin A. 
Published: March 2023

Abstract
Cement as barrier material have weaknesses because of inherent shrinkage and lack of robustness over time. In recent years shale barriers have become a likely alternative to cement in many instances. Shale is a natural material with an indefinite lifetime. There are, however, many aspects around using shale as well barriers, related for example to activation and qualification.
This paper presents a unified approach from an operational perspective. Firstly the relevant models for shale barrier formation are established. Then the loading required to establish a shale barrier will be defined both from a well pressure perspective and a thermal heating perspective. A mechanistic elastic-plastic model for shale deformation will be derived and coupled to the wellbore situation. Hydration of the shale also help establishing the barrier.
Several field cases are presented starting at defining potential shale barrier intervals from UCS logs coupled with an elastoplastic model to define barrier extent. The result is presented as a log showing radius to virgin formation. High MSE and drillability is another parameter identifying weak rocks. A drillability log will also be shown and correlated with the shale barrier extent from the UCS. Finally, after casing is set high end cement bond logs are used to confirm the barriers. The paper presents the field application, defining the optimal log and wellbore pressure conditions to establish an effective shale barrier.
Field Test Results for Real-time ROP Optimization Using Machine Learning and Downhole Vibration Monitoring - A Case Study
Authors: Robertson Ryan , Deans Aidan , Singh Kriti , Braga Daniel , Kamyab Mohammedreza , Cheatham Curtis , Borges Tatiana 
Published: March 2023

Abstract
A case study for a real-time field test of a machine learning (ML) ROP prediction and optimization algorithm and a vendor-neutral vibration monitoring system is presented for ten wells in Northeastern British Columbia, Canada. A novel auto-calibration feature adjusts the ML model in real-time to account for prediction bias. The paper is of interest to operators and service companies seeking to accelerate uptake of Artificial Intelligence (AI) by rig personnel.
A ten-well campaign in three target formations was drilled from one rig in the lateral sections to test the ML ROP prediction/optimization system. During the first two laterals, the operator office engineers visited the rig to train the rig team and gain their buy-in. For the remaining wells, tests were run in real-time advisory mode. Field test objectives were to develop trust in the ML model, validate real-time vibration monitoring tool with real-time downhole vibration data, and obtain feedback from the rig and office on functionality to accelerate uptake of AI.
Initially, the ML ROP model passed all success criteria in two of three formations, or four of six wells. One formation failed the ROP accuracy criterion because the predicted ROP was consistently too high, but the ML model accurately captured the variance. This led to the development of a novel automated calibration procedure that adjusts the "bias" of the machine learning ROP prediction in a manner like calibrating physics-based models (such as torque and drag hookload) using a calibration factor calculated in real-time by comparing predictions with actual ROP values. This enhancement enables meeting accuracy acceptance criteria and has opened the door for a broader application of the method in other formations and basins. To date the model has been successfully deployed for the lateral section and for bottomhole assemblies (BHAs) with a positive displacement motor.
The vibration monitoring system successfully provided real-time data to the operator at the rig and office that is generally available only to the MWD provider in real time, which enables the operator to gain new insights for situational awareness and decision making.
Feedback from rig personnel was very valuable and included new functionality, such as their ability to change parameter limits in the ROP system, which has been implemented and successfully used by the operator.
Data-Driven Machine Learning Modeling of Mineral/CO2/Brine Wettability Prediction: Implications for CO2 Geo-Storage
Authors: Tariq Zeeshan , Ali Muhammad , Yan Bicheng , Sun Shuyu , Khan Mohammad , Yekeen Nurudeen , Hoteit Hussein 
Published: March 2023

Abstract
CO2 wettability and the reservoir rock-fluid interfacial interactions are crucial parameters for successful CO2 geological sequestration. This study implemented the feed-forward neural network to model the wettability behavior in a ternary system of rock minerals (quartz and mica), CO2, and brine under different operating conditions. To gain higher accuracy of the machine learning models, a sufficient dataset was utilized that was recorded by conducting a large number of laboratory experiments under a realistic pressure range, 0 – 25 MPa and the temperatures range, 298 – 343 K. The mica substrates were used as a proxy for the caprock, and quartz substrates were used a proxy for the reservoir rock. Different graphical exploratory data analysis techniques, such as heatmaps, violin plots, and pairplots were used to analyze the experimental dataset. To improve the generalization capabilities of the machine learning models k-fold cross-validation method, and grid search optimization approaches were implemented. The machine learning models were trained to predict the receding and advancing contact angles of mineral/CO2/brine systems. Both statistical evaluation and graphical analyses were performed to show the reliability and performance of the developed models. The results showed that the implemented ML model accurately predicted the wettability behavior under various operating conditions. The training and testing average absolute percent relative errors (AAPE) and R2 of the FFNN model for mica and quartz were 0.981 and 0.972, respectively. The results confirm the accuracy performance of the ML algorithms. Finally, the investigation of feature importance indicated that pressure had the utmost influence on the contact angles of the minerals/CO2/brine system. The geological conditions profoundly affect rock minerals wetting characteristics, thus CO2 geo-storage capacities. The literature severely lacks advanced information and new methods for characterizing the wettability of mineral/CO2/brine systems at geo-storage conditions. Thus, the ML model's outcomes can be beneficial for precisely predicting the CO2 geo-storage capacities and containment security for the feasibility of large-scale geo-sequestration projects.
New Numerical Method for Sand Production Propensity Estimation
Authors: Subbiah Surej Kumar , Mohamad-Hussein Assef , Samsuri Ariffin , Jaafar Mohd Zaidi , Chen Ying Ru , Pearce Andrew , Ranjan Kumar Rajeev , Paramanathan Rajendra Nath , de Groot Lex 
Published: March 2023

Abstract
The sandstone reservoir rock failure during production may lead to sand production issues and may impact the economics of field development strategy, especially deep-water operation. The lifting cost can be higher as the issue can lead to metal-erosion, well integrity and oil/gas leakage. In the absence of a sand control mechanism (screenless-completions), the production rates often reduced to bound the severity of sanding and its consequences. In nutshell, the wrong decision for the type of completion prior to drilling and production may risk the financial feasibility of the field. Therefore, an accurate prediction of sand production volume/rates is essential during the well planning. Having this information upfront will able the operators to select the best sand-management plan for the well and field economically (best productivity and highest ultimate recovery while keeping the operating cost low. This paper reviews the ingredients required for sand propensity modeling, not limited to onset sanding drawdown but also the sand propensity (volume). A new proposed modeling technique for sand production propensity will be discussed. The new innovative modelling techniques (fully coupled with fluid dynamics) is powered by a new constitutive elastoplastic and damage model. The newly developed failure criteria give better insight for rock mechanical behavior honoring pre and post-failure stages enabling the usage for sand production analysis to estimate the sanding propensity which includes stress stabilization. Validation and comparison between laboratory testing and numerical modeling for sand production volume presented using the newly developed modeling techniques namely perforation cavity geometry stabilization and grid cell removal.
Research of Polymeric Surfactant as Multifunctional Monocomponent Oil Displacement Agent in EOR
Authors: Su Zhiqing , Xu Hui , Li Yingcheng , Sun Hui , Jin Jun , Wang Bin , Ma Aiqing , He Xiujuan , Sha Ou 
Published: March 2023

Abstract
SP (Surfactant-Polymer) flooding is one of the most common methods in Enhance Oil Recovery (EOR). However, chromatographic separation underground limits its efficiency due to the enormous difference in molecular size between polymer and surfactant.
A single-component oil displacement agent, polymeric surfactant (PolyS), was studied to solve the chromatographic separation. Properties were investigated under the reservoir conditions, including viscosity, interfacial activity, injectivity, adsorption, and core flooding.
With the increase of the active functional group content, the viscosity decreased, while the oil-water interfacial activity increased. The viscosity of PolyS was higher than 10mPa∙s, and interfacial tension (IFT) was lower than 3×10-2 mN/m at 2500 mg/L PolyS in the brine with a salinity of 66560 mg/L at 72°C. The middle phase emulsion was formed when mixing crude oil and PolyS solution, indicating that PolyS had better capability to emulsify crude oil than commercial polyacrylamide (PAM). Furthermore, the adsorption amount of PolyS on silica with diameter of 100-150 μm was 1.16 mg/m2.
PolyS can be easily injected into sandpack with different permeabilities from 300 mD to 1000 mD. The oil displacement results showed that an improved oil recovery of 26.15% OOIP was achieved with an injection of 0.3 PV PolyS solution containing a 2.04 mol% active functional group, which had both low IFT and high viscosity. As a comparison, only 20% OOIP was obtained for commercial PAM.
The Application of Scale Inhibitors for Downhole Capillary Injection Under Ultra High Temperature
Authors: Shen Dong , Stewart Jonathan , Chao Kung-Po , Cook Stuart 
Published: March 2023

Abstract
Scale inhibitors have been widely used in oil and gas production as well as oil processing plants to control the formation of mineral scales. However, most scale inhibitors tend to lose efficiency as scaling temperatures above 400°F due to the thermal degradation of the chemicals. A customer in the Middle East reviewed their scale management strategy for a steam flood project with application temperatures up to 450°F and requested a suitable scale inhibitor for downhole capillary injection to prevent the formation of calcium carbonate and calcium sulphate scales.
Several scale inhibitor products were selected for scaling inhibition tests based upon known high temperature stability. Dynamic tube-blocking test results indicated that three selective inhibitor products were able to mitigate the formation of calcium scales at 450°F effectively. These three products are fully compatible with the formation waters up to 10,000 ppm and were selected for further thermal stability and corrosion tests. Product A and B had good general corrosivity results, but product B was considered to fail the capillary approval test as there was extensive solid generation/phase separation observed after the thermal aging process at 450°F. Product C was also considered unsuitable as it showed aggressive corrosion rates.
In conclusion, Product A is recommended for downhole capillary application in this steam flood project based upon the test results in this study and its previous successful downhole capillary application in the field at 400°F. Due to the high application temperature, special precautions may be necessary for preservation of the capillary string.
A Methodology to Evaluate Video Analytics for Drilling Safety Operation using Machine Learning
Authors: Alkaabi Sultan , AlAzri Ahmed , AlZakwani Saud , Altamimi Fadhil 
Published: March 2023

AbstractIn Petroleum Development Oman (PDO) mission that committed to empower employees with the needed capabilities and fuel innovation, efficiency and more importantly achieve and sustain a 100% Health, Safety and Environment (HSE), by transforming the way of handling HSE events by moving from reactive to proactive approach. Drilling operations represent a challenging environment due to human factors that prone focusing on operations mainly instead of safety of Personnel Protective Equipment (PPE). Surveillance cameras are installed in various locations in rig floor and contribute to security and safety. However, the current methods of video analytic in floor rigs are weak in the long-term sequence of nodes with missing and abnormal error value such nighttime, low illumination which causes poor images. In a proof-of-concept exercise, PDO has been provided the AI Solution to overcome all above limitation to develop AI Models based on drilling operation on rig floor. Consequently, this paper presents machine learning pipeline that is validated and evaluated the vendors Video AI detection of HSE violations of PPE and restricted zone access on the rig floor that shared video dataset. The pipeline can be described in two parts. Due to the complexity of the use case that usually difficult to be managed in-house, we propose a method to bring different algorithms solutions from different vendors where the evaluation is managed in-house. In this, we present a framework for video analytic evaluating safety operation drilling in floor rigs. This framework contains the data of video source that collected, annotations guidelines to support necessary data quantities for the best machine learning approaches, performance metrics, and tools that containing scoring baseline models to be able compute amazing performance output regarding annotated ground truth data. The benefit of this study was to address some challenges of video object analytic and tracking beyond evaluation framework that enables a significant comparison of Machine learning models, provides AI vendors with sufficient data for the exploration the automatic modeling approaches, encourages the incorporation evaluation the techniques with process development, and contributes valuable oil and gas drilling that will demonstrate very useful to Computer Vision (CV) research for next years.
Tumor growth ameliorates cardiac dysfunction
Authors: Awwad Lama , Shofti Rona , Haas Tali , Aronheim Ami 
Published: March 2023

Abstract

Heart failure and cancer are the most deadly diseases worldwide. Murine models for cardiac remodeling and heart failure demonstrate that cardiac dysfunction promotes cancer progression and metastasis spread. Yet, no information is available on whether and how tumor progression affects cardiac remodeling. Here, we examined cardiac remodeling following transverse aortic constriction in the presence or absence of proliferating cancer cells. We show that tumor-bearing mice display reduced cardiac hypertrophy, lower fibrosis and improved cardiac contractile function. We further identify tumor-dependent M1-to-M2 polarization in the cardiac macrophage population as a mediator of the beneficial tumor effect on the heart. Harnessing cancer paradigms that are involved in tumor-dependent improved cardiac outcome may provide novel therapeutic strategies for cardiovascular diseases.