bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Multi-Disciplinary Integrated Geosteering Workflow for Drilling Horizontal Wells
Authors: Xue Jie. , Yu Ting. , Quan Min. , Bai Xian. Feng. , Yang Yao. , Cui Ji. Ning. , Li Fei. Fei. , Bo Jiangwei. , Xu Da. Wen. , Di Xiang. , Su Ming. , Liu Kun. , Jiao Cheng. 
Published: February 2025

Abstract
Block A is a green gas field in the southern Ordos Basin of central China. The S23 layer is the major payzone and is developed by horizontal wells. However, due to complex fluvial reservoir architecture and heterogeneity, lack of well control and local structural fluctuations, horizontal well geosteering is a very challenging task. To improve sandbody penetration ratio in the horizontal wells in this S23 resevoir, a multi-disciplinary integrated workflow for horizontal well placement has been devised based on the analysis of geological, geophysical, and real-time drilling data of the S23 reservoir
The geosteering workflow has been constantly improved and enriched by updating the understanding of S23 reservoir distribution from drilled wells and comprehensive seismic analysis. The workflow unfolds in four steps: 1) S23 reservoir prediction based special logging and seismic risk maps 2) under guidance of offset well correlation and seismic structural interpretation to support well placement and target point prediction. 3) construct pre-geosteering model and adjust the drilling trajectory to improve the landing success. 4) apply structural data, sedimentary facies, and seismic information to build finely gridded geosteering model, then combine the mud-logging data and engineering parameters to make real-time adjustment to keep trajectory into the reservoir. This integrated geosteering workflow has been implemented in Block A successfully to handling well with reservoir uncertainties and shown excellent judgment and higher sandbody penetration ratio in S23 horizontal wells.
Because of the application of this innovative integrated method, from 2018 until now, the horizontal wells landing successful ratio improved from 88% to 97.6%. To date, 140 horizontal wells have been drilled in this block A, the average horizontal section length reaches 1015 m, and the sand body penetration ratio improves from 81% to 87%, the overall ratio is 85%. The integrated workflow is successfully combines geology, geophysics and engineering information, which makes the real-time guidance and adjustment come true, it has been beneficial for the well placement and drilling of horizontal wells, especially to optimize geosteering in the complex fluvial reservoir.
Enhancing Casing Drill Out Consistency and Unconventional Interbedded Drilling Efficiency with in-Bit Data Capture and Shaped Cutter Technology
Authors: Jafri M. O. , Jamal S. , Vrnak K. 
Published: February 2025

Abstract
Drilling out casing equipment with a Polycrystalline Diamond Compact (PDC) bit is a challenge, as it can result in prematurely Pulling Out of Hole (POOH) while drilling formation due to bit damage. This paper introduces a novel drill bit design approach for efficiently cleaning out casing equipment and drilling highly interbedded formations in one run in unconventional wells. This was accomplished by leveraging downhole at-bit data in combination with optimal placement of innovative shaped cutters along with improved nozzle configuration to enhance drilling efficiency and durability in challenging drilling environments.
The approach started with the deployment of a legacy drill bit design having traditional round cutters equipped with downhole sensors to drill out casing equipment and target formations. Data from these runs were then analyzed to optimize drilling parameters, both during drilling of the casing equipment, and the interbedded transitional formation. Subsequently, utilizing insights from the data analysis, a new drill bit design incorporating shaped cutters and improved nozzle configuration was developed to further mitigate impact damage and improve overall drilling performance.
Preliminary results demonstrated the effectiveness of the approach in significantly enhancing drilling efficiency and durability, leading to the successful completion of shoe-to-shoe runs. Notably, the bit dull post-run revealed a reduction in impact damage on the new design featuring shaped cutters, thereby contributing to extended longevity and improved drilling performance. Furthermore, the optimization of hydraulics played a crucial role in mitigating bit balling in sticky formations thereby enabling even higher Rates of Penetration (ROP). Ultimately, this study underscores the potential for scaling this holistic approach to effectively address the challenges associated with efficiently cleaning out casing equipment and drilling in complex geological environments.
This paper presents a rounded approach to drill bit design by integrating downhole at-bit data, hydraulics optimization and innovative cutter design to tackle drilling in highly challenging environments. Using this multi-faceted approach to bit design offers practical solutions for improving drilling efficiency and reducing Non-Productive Times (NPT) for customers.
Delineating and Decoding the Qualitative Interpretation of Gas Lift Instabilities in the Continuous Gas Lift Wells of Mehsana
Authors: Chanchlani K. , Sukanandan J. , Devshali S. , Kumar V. , Kumar A. 
Published: February 2025

Abstract
Gas Lift Real Time Monitoring System (RTMS) provides the real-time gas injection pressure, casing head pressure, and tubing head pressure of gas lifted wells. This system captures the surges in the casing head pressure and/or tubing head pressure, causing chaotic and undesirable fluctuations. The production from continuous gas lift wells can be severely unstable and behave as intermittent gas lift. The trend of production loss is the norm for unstable gas lift systems. The oscillating flow affects the processing equipment and can lead to grid shutdown. Casing heading is prominent instability in the low casing head pressure wells, producing a flower-like pattern in the RTMS monitoring of the continuous gas lift wells. Hydrodynamic slugging can induce the dynamic well loading. Analysis also indicated the possibility of density wave oscillation-type dynamic instability due to flowline bean restriction at the surface. Triggering the simplified approach of active using contemporary methods creates marvel in the continuous gas lift installations. The stable operational range of the wells can be construed by mapping the types and characteristics of different gas lift instabilities. The types of gas lift instabilities and their characteristics are recognized at the field scale from the RTMS. The discussed case studies steered the surge in the production rate using innovative methods and demarcated the wells with tubing annulus communication problem. The subsequent analysis and remediation utilized the novel multiple converging gas lift ports downstream of the gas lift valve (GLV), gas injection rate optimization, and rocking using the tubing connected from annulus to tubing. The successful application of this method supplemented with the cases staggered the gas lift network intricacies by detecting the non-flowing wells. Significant production gain is realized by daily monitoring and optimization of 120 continuous gas-lifted wells.
Enhancing Wellbore Positioning and Operational Efficiency Through Advanced Surveying Technologies in ERD Project
Authors: Nunez L. E. , Rodriguez J. A. , Hoyos J. M. , Zachman N. , Campos N. , Lopez C. , Villavicencio J. 
Published: February 2025

Abstract
This paper illustrates the optimized way medium and extended reach wells were drilled with a focused strategy on caring for the environment with the use of innovative technologies. The acquisition of redundant well surveying was processed using all available data to obtain the most accurate position (MAP). Post processing of high density definitive dynamic surveys (DDS) allowed the evaluation and analysis of wellbore tortuosity. The impact on the operational results of cutting-edge survey processing is to reduce well drilling risk and decrease the drilling and environmental costs (CO2 savings).
In Colombia's Llanos Orientales Basin, the development of an environmentally restricted reservoir required advanced high-displacement and extended-reach drilling strategies. Complexities arise from the high density of drilled wells, which necessitates precise trajectory management to avoid collisions and ensure safe reservoir access. To tackle this, several technologies have been applied, starting with Gyro technologies (Drop and while drilling) and also after an economic evaluation recommended acquiring local magnetic In field reference measurements, which allowed the reprocessing of magnetic surveys (MWD) using In-Field Referencing (IFR). This reduced positioning errors associated with crustal magnetic variations, alignment corrections for the BHA (SAG), and multi-station analysis (MSA) for statistical accuracy.
Applying IFR reduced drilling risk by reducing EOU not only in while drilling wells but also from previous drilled wells with MWD technologies. This led us to reduce trajectory tortuosity and complexity from planning, improving well positioning and helping avoid remedial costs by minimizing collision risks. These methods also enabled enhanced wellbore positional certainty, allowing safer, continued operation without halting neighboring wells. As a complement to this magnetic model data acquisition technique, an innovative processing known as MAP (Most Accurate Position) was carried out in the last extended well drilled. This approach integrates surveys data obtained from gyroscopic tools, specifically Coriolis Vibratory Gyroscope (CVG), with magnetic measurements corrected via IFR in a holistic model, yielding a significantly smaller uncertainty ellipse with minimal associated error.
It is the first time that this type of modeling has been used in Colombia, which has allowed reducing the size of uncertainty ellipses by up to 50% for both the well under execution and the existing ones. This processing can be applied in real-time without impacting the development of the operation, maintaining less tortuous and better-positioned drilling trajectories. And to add a novel processing, an specific tortuosity analysis was carried out using MWD DDS measurement, to understand in a better way the casing runs, and the impact on the tortuosity in the hole pass through size.
Machine Learning Models for Permeability Prediction Using Petrophysical Well Logs: A Novel Approach
Authors: Alatwah Saleh 
Published: February 2025

Abstract
This study investigates the application of machine learning algorithms for permeability prediction in diverse geological settings, focusing on carbonate and clastic reservoirs. Four machine learning algorithms—Support Vector Regression (SVR), Random Forest (RF), XGBoost, and LightGBM—were evaluated using datasets from the Costa Field (carbonate) and Volve Field (clastic). The research emphasizes the impact of feature engineering and hyperparameter tuning on model performance. Results show significant improvements in prediction accuracy, with R2 scores reaching up to 0.8 for individual wells in the Costa Field and ranging from 0.76 to 0.84 across different formations in the Volve Field. The study highlights the potential of machine learning as a cost-effective and efficient alternative for permeability prediction, especially in scenarios with limited core data availability.
A Novel Technique to Control Sand Production from Mature Consolidated Sandstone Formation by Using Sodium Phosphate to Enhance the Formation Strength
Authors: Alameen M. Basheer , Almansour Abdullah , Elraies Khaled A. , Mohyaldinn Mysara , Eshaba Abdulmuez 
Published: February 2025

Abstract
It is known that sandstone formations often experience significant sand production when water saturation increases, especially in mature fields. Essentially, the amount of sanding mainly depends on the change in rock strength. Therefore, this paper examines the silica dissolution mechanism to establish a correlation between silica dissolution and rock strength as a function of water saturation. Additionally, the study explores the potential of sodium phosphate as an inhibitor to mitigate dissolution and enhance formation strength. A combination of static and dynamic experimental approaches was employed to establish a correlation between silica dissolution and rock strength as a function of water saturation. In the static approach, crushed core fine and coarse particles are utilized under different reservoir conditions to examine the silica dissolution. For the dynamic core flood test, silica dissolution was investigated as a function of water saturation in the presence and absence of sodium phosphate as an inhibitor to prevent dissolution. Then, core strength was recorded using unconfined compressive strength. Silica dissolution was detected by using a UV-Vis spectrophotometer. The results from the static experiments revealed that silica dissolution is mainly influenced by the pH and temperature of water. Additionally, water salinity impacts the amount of silica dissolved, indicating sodium chloride and potassium chloride have a higher effect on dissolution than magnesium chloride and calcium chloride. Moreover, fine particles have more dissolution compared to coarse particles. The core flooding test shows a clear relationship between increased water saturation and accelerated dissolution rate, consequently reducing core strength. Core strength decreased from 35.4 MPa (dry condition) as water saturation increased from 20% to 100%. This decrease was accompanied by an increase in silica dissolution. The reduction in core strength was consistent, reaching a maximum drop at 100 % water saturation, where it declined to 19.5 MPa, coinciding with the peak rate of silica dissolution, measured at 14 mg/l. Regarding the inhibitor effect, sodium phosphate notably suppresses silica dissolution, particularly at concentrations of 0.1 wt% and 1 wt%. This inhibition effectively maintains core strength near its original value. This study contributes novelty by understanding the main reasons contributing to sand production in mature, consolidated sandstone as water saturation increases. Additionally, it proposes an innovative approach to mitigate sand production by introducing an inhibitor (sodium phosphate) to control the reduction in sandstone strength through reducing silica dissolution.
Optimization Method and Application of Deliverability Testing for Low-Permeability Gas Condensate Wells
Authors: Yang Yi , Cao Yang , Yu Weiqiang , Zhang Guohao , Yang Zhicheng , Lv Zuobin , Xing Shanchuan 
Published: February 2025

Abstract
The deliverability testing of gas wells is an important technology to master the scale of oil and gas reservoirs and assist in making development plans. Conventional reservoirs generally use storage pressure gauges for testing, and through deliverability testing with multiple rates, the deliverability equation is obtained using binomial regression method. For low-permeability condensate gas reservoirs, abnormal binomial productivity equations often occur during well testing and calculation. We will analyze the main influencing factors and summarize a targeted testing and interpretation plan based on the dynamic parameters of the wellhead.
By analyzing the production performance of low-permeability condensate gas wells during testing, it has been determined that the main influencing factors that cause anomalies in calculating the binomial productivity equation include: average formation pressure error, condensate oil precipitation, unreasonable testing system, etc; Based on the critical flow rate calculating, production gas oil ratio and wellhead pressure of the test well, the minimum and maximum testing system thresholds for condensate gas wells were determined, which assisted in setting reasonable intervals for testing rates and formed a guiding process and method for selecting deliverability testing sequence.
For the deliverability testing of low-permeability condensate gas wells, the energy replenishment in the inner layer of the gas release radius is slow, and the bottom hole flow pressure of the large oil nozzle cannot reach stability for a long time; And in many cases, the pressure difference between formation pressure and dew point pressure is very small. The condensate gas reservoir begins to precipitate condensate oil in the early stage of development, which disrupts the correspondence between production rate and bottomhole pressure, leading to abnormal calculation of the binomial deliverability equation. Dynamic data such as wellhead oil pressure, production gas oil ratio, and production stability can reflect the true flow state of the reservoir and wellbore under different testing rate. We use these dynamic data of the wellhead and the phase characteristics of the fluid itself to determine whether the testing rates is reasonable and whether it has reached a stable state. Through actual test well examples, it has been verified that most of the wells in the target reservoir conform to the above summarized rules, providing an efficient and accurate guidance method and standard process for on-site deliverability testing and deliverability equation calculation.
Our future work will be to study and summarize other types of test wells that often lead to abnormal deliverability testing, such as low porosity and permeability, water and gas wells, etc. This will provide excellent real-time guidance for on-site testing.
NextGenAI-Driven Enhanced Observability & Security Suite for Edge Computing Fleet
Authors: Arabi Hakim , Liu Minyue , Temer Elias , Misha Anna , Xu Lina 
Published: February 2025

Abstract
The ongoing adoption of Industry 4.0 in the oil and gas sector, especially within drilling operations, has significantly accelerated the deployment of digital technologies at the edge. With this rapid growth, there is a pressing need for an effective framework to proactively monitor edge deployments and enhance operational resilience. In 2023, an advanced monitoring system featuring Elastic Fleet Management was introduced to address this need, combining real-time performance tracking with incident alerting capabilities integrated with tools such as PagerDuty. This approach established new benchmarks for reducing nonproductive time (NPT) and improving service delivery by providing site reliability engineering (SRE) teams with critical tools to maintain high standards amid continuous expansion.
Building on this foundation, we propose an artificial intelligence (AI)-powered framework that goes beyond traditional observability. Leveraging autonomous capabilities, the system will intelligently analyze a wide range of logs-including software, system, and firewall activities-enabling proactive issue detection and self-management. The next phase involves the deployment of generative AI (GenAI) enhancements, capable of not only identifying anomalies but also autonomously resolving detected issues without manual SRE intervention. This evolution marks a shift toward fully self-managing operations, setting the stage for a transformative leap in operational efficiency, safety, and service quality across geographically distributed drilling sites.
Drone-Based Solutions for Asset Integrity: Development of NDT Drone and 3D FPV Payload for Asset Remote Testing and Inspection
Authors: Campaci R. , D'Angelo S. , Borzone T. , Madia L. , Favaretto M. , Lippiello V. , Vignali A. 
Published: February 2025

Abstract
This paper presents two advanced drone-based solutions developed for asset integrity and industrial inspection applications: a Non-Destructive Testing (NDT) drone and a 3D First-Person View (FPV) camera system. The NDT drone integrates a lightweight robotic arm with ultrasonic probe as end effector for thickness measurements of metal surfaces. The 3D FPV system provides stereoscopic vision with an automatically vergence-compensated zoom for enhanced depth perception during remote inspections. In the field of aerial inspection technologies those solutions represent significant advancements, offering improved capabilities and accuracy. This document aims to detail the design, implementation, and testing of both the solutions.
Well Trajectory Optimization has been Successful in Delivering 1000 BOPD by Revisiting Seismic Pre-Stack Depth Migration PSDM to Minimize Structural Uncertainty. Case Study: BMAX-12ST Infill Well, Brown Field, Pertamina Offshore, Northwest Java
Authors: Fransisco Lambertus , Vico Hendro , Setiawan Priantoro Kartika Dani , Dewi Yasinta , Radiansyah Sandra 
Published: February 2025

Abstract
For more than 12 years, the Brown field has not carried out an infill well drilling campaign. Production in this field only involves maintaining the production base through workover, well work, and zone change activities. To increase the recovery factor in the Brown Field, the team carried out a drilling campaign for 4 infill wells to produce oil from BM-35A and BM-36A zones, of which 2 wells were executed in early 2023.
Determining optimal infill well placements in heterogeneous mature reservoirs is a critical and challenging task that has a significant impact on the recovery performance and economic revenue of subsurface remaining oil resources. An integrated framework is revisited to attain the best-obtained target location based on updated PSDM anisotropy and hydraulic fracturing strategy. In order to achieve the target, the new PSDM was reprocessed internally to rebuild the VTI (Vertical Transverse Isotropy) velocity model using a high-resolution grid in order to solve velocity anomalies near thin carbonate flanks. This result was confirmed by the well velocity trend.
The new PSDM has captured that the old trajectory crossed a minor fault and could potentially penetrate the lower 30 feet of the down-thrown structure, impacting the hydraulic fracturing strategy. Based on this seismic, we optimize the well trajectory to a new sweet spot by shifting the hit point to the higher area in the east, a geologically formed three-way dip closure caused by a minor fault. The target location has a thicker reservoir based on sandridge facies distribution. For optimization purposes, the hydraulic fracturing job incorporates a comprehensive study of geomechanics and low-viscous fluid utilization, which led to optimum fracture geometry and less fluid residue. This study successfully supported the hydraulic fracturing strategy and delivered 1000 BOPD initial production which is three times higher than the prognosis.
The success of the infill well occurs due to data integration and lessons learned from existing wells. The results of the optimization of the BMAX-12ST well trajectory not only provide good oil production but also increase the reserve and economy of the well.