bluuebunny/crossref_metadata_2025_split huggingface dataset:
Real-Time AI Geosteering for Horizontal Well Trajectory Optimization
Authors: Peshkov G. , Pavlov M. , Katterbauer K. , Al Shehri A. 
Published: November 2023

Abstract
Active petrophysical geosteering in reservoir formations has become a very promising practice and commonplace to improve express formation evaluation and maximize hydrocarbon production from reservoirs. The present study showcases the effectiveness of utilizing artificial intelligence (AI) framework to process resistivity logging while drilling (LWD) data for the purpose of real-time optimizing well trajectories and maximizing hydrocarbon production in pay zones during drilling horizontal section.
We introduce a novel framework that automatically adjusts planned well trajectories during horizontal drilling. The framework takes the planned wellbore trajectory, reservoir model porosity, and ultra-deep resistivity LWD data as input. Hydrocarbon saturation volume is then calculated using the Archie equation. Subsequently, optimization algorithms correct the planned trajectory to maximize wellbore production using hydrocarbon saturation volume. The framework delivers an optimal wellbore trajectory performing real-time formation evaluation, guiding the drill bit through highly saturated pay zones.
The proposed framework was tested on a 2D synthetic dataset using various optimization algorithms, including reinforcement learning algorithms for continuous action spaces (PPO, DDPG, TwinDDPG) and Q-learning and evolutionary algorithms. The evolutionary group of optimization algorithms achieved the highest efficiency with baseline hyperparameter settings, improving cumulative oil saturation per drilled meter by up to 32.5%. Reinforcement learning algorithms needs to be further explored because they have promising results but still high computational complexity. The evolutionary algorithm was then verified on a 3D Groningen field dataset, determining optimal hyperparameters such as differential evolution strategy, population size, mutational constant, and maximum number of iterations. The framework improved cumulative oil saturation per drilled meter by up to 6%, significantly increasing the average number of penetrated hydrocarbon-saturated pay zones along the drilling path.
The developed AI-based framework presents an innovative approach for real-time automatic correction of well drilling trajectories, maximizing well productivity. This method can significantly aid in the interpretation and optimization of decision-making related to geosteering.
Real-Time Ultra-Deep Azimuthal Resistivity Inversion Helps to Maximize Asset Value in West Kuwait by Locating Uneven Oil-Water Contact
Authors: Gezeery T. , Halawah Y. , Al Haddad M. , Al Sabea S. , Abdulkarim A. 
Published: November 2023

Abstract
The Burgan sandstone reservoir in the Minagish field of Kuwait is a complex depositional sequence that makes targeting Upper Burgan sands unpredictable due to channeling limiting the reservoir exposure. The area is complicated further by oil-water contact (OWC) uncertainty due to the long history of oil production. The objective of the well was real-time OWC mapping to provide reservoir insight, maximize pay zone exposure and extend the well life through optimizing the completion and production regime.
Recent production pulsed-neutron capture (PNC) logging in an offset well showed watering in the Upper Burgan reservoir. This might indicate a change in the level of the OWC or water coning. Utilization of an ultra-deep azimuthal resistivity (UDAR) mapping service was planned to help locate the OWC below the well trajectory and simultaneously identify and track the desired target sandstone sequence. UDAR has proven its capability to map reservoir boundaries and the OWC in real time, during drilling, earlier than with traditional methods. This facilitates real-time geosteering to drill the well in a single run in the productive zone.
The wellbore was placed in the desired zone by using UDAR real-time 1D inversion services. While drilling, it was discovered that the OWC was at uneven depths compared to what was expected. The reservoir management team obtained important information to update the oilfield development. UDAR services helped to increase reservoir exposure of the well in the Burgan sand of the Minagish oilfield and enhanced the understanding of the sand deposition structure. It was evident that PNC results in the producing offset well do not represent the OWC level throughout the field; instead, localized measurements may be affected by water coning in that specific area. This information led to a change in the field development strategy.
The UDAR real-time 1D inversion enabled optimization of the completion design and perforation intervals, and the understanding of the reservoir potential has been improved. The accurate OWC level evaluation will allow to place more production wells in this location.
Automating the Well Planning Process to Deliver Auto-Updated and Coherent Drilling Programs
Authors: Murray T. , Suryadi H. 
Published: November 2023

Abstract
Modern well planning requires extensive collaboration from multiple domains to design and execute increasingly complex wells. The iterative process requires many specialists and their respective engineering tools, to collaborate in the pursuit of an optimal design for a given well objective. The growth of these specialisms has, in many cases, led to a fragmented landscape that hinders efficiency, coherency and comprehensive risk assessment.
This paper highlights the intricate interactions between sub-domains in well planning, emphasizing the need for a more holistic approach. It continues to introduce a new transformative solution that enables engineers to streamline design iterations, seamlessly collaborate and focus on a broad range of design concepts. Central to this, is an interconnected framework that synchronizes all well design elements and their corresponding operational activities. By introducing key concepts like the "effective wellbore geometry " and "automated engineering analysis " we aim to demonstrate how this sophisticated infrastructure can automatically generate engineering simulations, to provide instant design validation to end users. The holistic, cross-dominant nature of these validations is unprecedented and opens the door to a true step change in planning efficiency and quality.
The paper later identifies some challenges and solutions associated with user collaboration in a cloud native application; striking a balance between freedom to experiment and seamless data sharing with team members. Exploring collaboration models further, concepts such as multi-plan comparison and advanced sensitivity analyses are introduced and described in detail.
Lastly, the technology and concepts that enable the generation and delivery of an "automated drilling program " are highlighted. This notable innovation promises significant potential time saving and improvements to the coherency of documentation typically generated as the culmination of the planning effort.
Robust Subsurface Drilling Hazards Assessment Reduces Well Drilling Cycle and Geological Non-Productive Time in an Onshore Pre-Caspian Basin Oil Field
Authors: Zhumadilov Ulan , Baktybayeva Kalampyr , Tlepbergenov Nurbolat , Manakhayev Ruslan , Sargunanov Marat , Puche Ernesto 
Published: November 2023

Abstract
Subsurface hazards assessment (SSHA) is an essential part of the well planning stage. Successful well execution depends on reducing geological uncertainties associated with hazards and it might prevent unexpected geological non-productive time (GNPT). Ultimately, SSHA can prevent possible catastrophic wellbore failure and loss of control in the drilling operation. The Pre-Caspian basin with its three megacomplexes has different geological hazards and requires unique drilling practices. Hazard mitigation plan can be developed both during well maturation and execution stages by acting accordingly. The approach should incorporate integrated analysis of geological, geophysical, and drilling data. Detailed SSHA and mitigation plan development are valuable constituents and basements for planning safe and cost-effective execution actions. The GNPT incurred due to insufficient recognition of geological uncertainties and underestimation of hazards can cost extra capital up to 30% of the total well execution expenditure. In addition, detailed SSHA is critical to deliver wells as designed ensuring reservoir penetration, formation evaluation and completion installation objectives are achieved fully, and future production is not compromised.
Calcium Sulfate Dissolution Using Lactic Acid
Authors: Alqahtani M. F. , Alissa F. M. , El-Demellawi J. K. , Bamigdad S. A. 
Published: November 2023

Abstract
There has been a global surge in scale challenges across the oilfield industry, surpassing other flow assurance challenges. In principle, scale refers to the deposition of mineral solids (primarily inorganic), such as calcium carbonate, calcium sulfate, or barium sulfate, that can accumulate and obstruct flow pathways in various industries, including oil and gas production, water treatment, and other industrial processes. Scale formation can lead to reduced production rates, increased energy consumption, equipment damage, and operational disturbances. Hence, the mitigation and prevention of scale deposition have become pivotal for maintaining high-performing production processes. In this regard, among the known scales, the calcium sulfate scale, in the form of gypsum (CaSO2.2H2O), is deemed challenging for many applications. This type of scale is usually caused by mixing incompatible waters. CaSO2.2H2O is an acid-insoluble scale; thus, it requires an effective scale dissolving recipe. Herein, we demonstrate the use of lactic acid (C3H6O3) as an emerging green chemical to remove gypsum deposits in the presence of different bases, including potassium and sodium carbonates and hydroxides. Different scale removal recipes were developed comprising mixtures of lactic acid with individual bases or a mixture of two bases. We show that, generally, hydroxide bases have exhibited lower performance, particularly potassium hydroxide, compared to their carbonate counterparts. Nonetheless, potassium carbonate, in particular, has offered a better performance compared to sodium carbonate. Incorporating lactic acid with the experimented bases has further improved the performance of the developed recipes, thanks to the induced synergistic effect, specifically with potassium carbonate. The latter has also demonstrated the ability to polymerize lactic acid when coupled with another base, such as sodium hydroxide or potassium hydroxide. Noteworthy, using sodium carbonate has resulted in much lower performances when coupled with the other hydroxide bases. Therefore, mixing two bases when dissolving calcium sulfate is not always the optimum choice as it brings other negative consequences.
Estimation of Gamma Ray Values with Deep Learning from Seismic
Authors: Karimli J. , Yeleskina T. , Shafiyev A. , Asgarov H. , Malikov R. , Mammadov O. , Shahsenov I. 
Published: November 2023

Abstract
Seismic inversion is pivotal in the oil and gas industry, aiding geophysicists in understanding reservoir characteristics. Despite its widespread use, the limitations of seismic data, like low resolution, introduce uncertainties that impede direct application. This study introduces an innovative method to estimate 3D Gamma Ray data from seismic reflectivity, reshaping reservoir understanding and management.
The study's goal was to predict 3D Gamma Ray data and its uncertainty via seismic reflectivity. This was achieved by employing Functional Convolutional Neural Networks (FCNNs) and Continuous Wavelet Transform. By merging well data and seismic information using signal processing and deep learning, accurate forecasts of Gamma Ray values were accomplished. It's worth noting that this manuscript constitutes as a continuation of the scientific research project initiated by Shahsenov et al. in 2022. The authors describe the updated methodology, the improvements achieved in the results, as well as any alterations made to the methodological framework.
The quality of prediction was validated through several statistical techniques, ensuring robustness. Blind wells were thoughtfully integrated into various analyses to facilitate a comparison between actual and predicted log values. The outcomes of these evaluations, promising in nature and showcasing notable advancements over the earlier work, are represented visually and in detail through the report.
In summary, this research pioneers a seismic inversion shift and builds upon prior research (Shahsenov et al., 2022). The combination of seismic reflectivity and deep learning allows precise prediction of 3D Gamma Ray values. By combining well and seismic data, the challenge of sparse logs is addressed, empowering geophysicists for more effective reservoir management. This enhanced reservoir understanding promotes data-driven decisions in the oil and gas sector.
Characterize to Stimulate: A Novel Field Development Approach in Tight Cretaceous Mishrif Reservoir, Minagish Field, Case Studies from West Kuwait
Authors: Ziyab Khalid , Patra Milan , Abu-Eida Abdullah , Akbar Bader 
Published: November 2023

Abstract
To unlock Mishrif reservoir potential in West Kuwait, a new development strategy involving analysis with Distributed Temperature Sensing (DTS) and downhole intervention with instrumented coiled tubing (Active CT) followed by high-rate stimulation by bull-heading has been applied to the tight carbonate formation. The goal was to find a cost-effective stimulation strategy that would increase the number of productive wells through an integrated production enhancement project approach.
The operation encountered various challenges, primarily driven by a high-permeability areas across the open hole, which was detected by DTS. Modifications were made to the CT stimulation procedure, including diversion techniques such as high-pressure jetting, dual injection and the pumping of a near-wellbore fully degradable diverter composed of a customized blend of multimodal particles and degradable fibers to temporarily isolate the highly permeable streaks. Real-time downhole telemetry had a paramount importance in ensuring the injection rate was kept below preset pressure limits and in monitoring downhole dynamics for optimal use of the high-pressure jetting tool. In most of the interventions, following the CT stimulation, a second post-stimulation DTS log was conducted to evaluate the fluid coverage and effectiveness of the diversion strategy allowing for further adjustment of the bullhead stimulation program for an optimum fluid coverage and avoiding the high-intake zones.
Wellbore Stability Analysis Using Stochastic 1D Geomechanics and Plane of Weakness (PoW)
Authors: Abdi Hadi Ashtiani , Alward Wassem 
Published: November 2023

Abstract
Wellbore stability models traditionally rely on inputs derived from rock physics models and empirical correlations, often iteratively adjusted using drilling observations and Mechanical Earth Models (MEM) predictions to obtain deterministic solutions. Given the inherent uncertainty in these parameters, scenarios with varying levels of uncertainty are commonly considered. Previously, assessing the impact of planes of weakness (PoW) on wellbore stability predictions in one-dimensional (1D) scenarios was challenging. Weak planes exhibit lower cohesion and friction angles compared to intact rock, affecting the stability of the wellbore. This paper introduces a stochastic approach that integrates PoW into existing workflows, allowing for the evaluation of inconsistent and non-intact rock masses’ influence on wellbore stability within the stable mud weight window. This approach can be employed across an interval, or just for a single depth, incorporating several sets of weakness planes.
The method presented in this paper employs Monte Carlo simulation to provide deterministic solutions for Plane of Weakness failure and incorporate individual uncertainties associated with key variables of MEM. Outputs include standard deviations and means, enabling the calculation of probability logs for various mud-weight window limits (e.g., breakdown pressure, kick pressure, shear failure). Additionally, image log-identified fractures are considered as Planes of Weakness, providing insights into the behavior of inhomogeneous or non-intact rock masses during drilling when drilling parameters fall outside the stable mud weight window.
This approach proves invaluable in addressing complex geomechanical environments characterized by uncertain subsurface pressures, stresses, rock properties, and the presence of PoW such as natural fractures. It aids in identifying significant sources of uncertainty, and guiding data acquisition, and rock-testing efforts. Furthermore, it enhances wellbore stability predictions in scenarios with limited calibration data. The paper showcases examples of its application in optimizing wellbore stability boundaries for proposed trajectories in the South of Iraq, highlighting its practical utility in real-world drilling scenarios.
Oil & Gas Exploration and Development with the Reverse Time Holography Technology
Authors: Erokhin G. , Erokhina M. , Safran K. 
Published: November 2023

Abstract
The article analyzes methods for constructing seismic attributes, which are based on two-stage data processing: on decomposition the initial common shot gathers in common image gathers, using the time-reversal algorithms and on synthesis a seismic attributes. It is shown that a detailed analysis of the joint behavior of two vectors: the velocity vectors in forward wave and the velocity vectors in time-reversed backward scattering wave provides detailed information about the medium. This is the essence of a new approach called RTH, which allows the acquisition of various seismic attributes at high spatial resolution. The new approach provides the solutions of prediction problems in oil and gas exploration, as well as problems in development using the drilling data and AI algorithms, at a new qualitative level.
Improving the Technology of Complex Hydrogen Thermobarochemical Treatment CHTBCE for Effective Use in Oil Wells With Weakly Consolidated Sandy Reservoirs
Authors: Kravchenko O. , Veligotskyi D. , Agaev U. 
Published: November 2023

Today, it is common practice to produce oil from failure-prone, weakly cemented reservoirs. The operators’ desire to increase production requires operating wells at their maximum capacity, and therefore leads to more aggressive drainage of the reservoirs with high oil flow from the pay zone to the well bore. At the same time, the oil filtration rate increases significantly, especially in the near well bore zone. This promotes the active movement of rock particles together with the production from the bottomhole formation zone to the well bore. Sand movement to the well bore and removal into the well itself leads to many unfavourable consequences, such as reservoir disintegration, up to the collapse of the reservoir roof, blocking of filtration channels in the bottomhole formation zone (BFZ), accumulation in the well bore with an overlap of the productive interval. All this prevents the product from entering the well, leading to abrasive wear, pumping equipment failure, etc.
These factors affect the quality of the filtration properties of the bottomhole formation zone, disrupt the hydrodynamic link between the productive formation and the well bore, resulting in its productivity drop. To date, there are several technologies aimed at consolidating the bottomhole formation zone and preventing sand removal. They are used depending on the design of the bottomhole, the time of operation, the geological and temperature parameters, the mechanical, and the chemical and combined methods of securing the formation rocks in the bottomhole zone of the wells. As a rule, the use of these technologies leads to a decrease in the filtration-capacitance properties (FCP) of the reservoir. These technologies fail to solve other common problems of well flow rate reduction, such as colmatization, asphalt-resin-paraffin deposition (ARPD), FCP reduction by oil-water emulsions, etc. At the same time, the methods of complex impact on the reservoir are now widespread to increase well productivity. Their application during one technological treatment exertsa multifactor physical and chemical effect on the rock and its saturating fluids, with several flow rate reduction factors being eliminated simultaneously. The controllability of the physicochemical processes employed in the oil production enhancement methods (OPEM) opens up prospects for their use to improve FCP with simultaneous reservoir consolidation.
Methodology of Creation of Artificial Core Reservoir Formations Using Geometric Design Methods
Authors: Kravchenko O. , Romanova T. , Veligotskyi D. , Homan V. , Agayev U. , Yaskov G. , Chuhai A. 
Published: November 2023

During the operation of oil wells, their flow rates decrease not only due to a reservoir pressure drop but also because the permeability of the bottomhole formation zone (BFZ) decreases because of the fall-out of asphalt-resin-paraffin deposits, colmatization by process fluids, formation of fracture particles, salt deposits, etc.
The productivity of such wells can be restored by applying various oil production enhancement (OPEM) methods. Choosing the most effective OPEM, developing the treatment design and predicting well productivity increase is currently done, as a rule, by being based on experimental studies with subsequent application of physical and computer modeling methods. At the same time, to determine experimentally the permeability change coefficient of the reservoir rock by implementing one or other OPEM, using natural cores is a desirable option. They are a source of unique information about the reservoir rock and the character of fluid filtration there-in. Natural cores are extracted from the well at the drilling stage and, as a rule, they are available either in limited quantities or are completely absent. In this case, experimental studies are carried out on artificial cores made by special technologies. At the same time, it is very important and relevant that they have morphological, mineralogical, and filtration-capacity properties (FCP) as close as possible to those of natural cores. Only in this case, we can talk about the adequacy of the physical model and the accuracy of the results of experimental studies, which, in turn, are the initial ones for mathematical modeling. Body text 2 paragraphs.