bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using an Advanced Geomechanics-Based Workflow to Prevent Wellbore Shear Failure When Drilling Across Depleted Formations
Authors: Omer Mohammed , Duarte Miguel , Fragachan Francisco E. , Alvarez Alfredo 
Published: February 2024

Abstract
Drilling laterally and in the direction of minimum stress assists in optimizing hydraulic fracture stimulation designs. However, it poses a huge risk of hole instability due to stress concentration while drilling across the minimum stress direction. Generally, when breakouts are encountered, the strategy is to increase the mud weight, but in scenarios where the mud weight window is very narrow, trying to avoid fracture initiation will potentially lead to shear failure or breakouts. This makes drilling highly challenging. One would need to have a deep understanding of the weak formations and plan a wellbore strengthening strategy to mitigate instability issues when drilling across these formations.
This research used a semi-analytical model based on the Gauss-Chebyshev polynomial to quantify wellbore strengthening. The model provided a comprehensive analysis of the formation strengthening in different scenarios and predicted fracture width distribution, coupled with the fracture initiation pressure. Combined with the mud loss volume, this algorithm helped quantify the loss and provided a strategy for corrective action. We used the learnings from the model to design a wellbore strengthening material to prevent shear failure of the weak formations or the formation with high porosity. This effectively prevented the wellbore from collapsing.
In this paper, we present the results from formations in the Middle East and Asia where this approach was used to predict the instability in the formation at the planned mud weight. The effect of the mud weight was quantified to predict the breakout so that the appropriate strategy was utilized for wellbore strengthening.
This integrated approach provides a workflow for drilling through depleted zones, weak formations, and challenging wells by considering stress behavior. Additionally, the case studies presented in this paper provide key information on mitigation strategies for unstable or weak formations.
Digital Emission Footprint Estimation as a Design Criteria to Fulfil Sustainable Development Goals
Authors: Majumdar C. , Naik C. K. , Garg A. , Suryadi H. , Dara A. K. , Hussain S. A. , Singh A. 
Published: February 2024

Abstract
This paper highlights a pioneering approach to address carbon emissions in the oil and gas sector. It emphasizes the growing focus on environmental sustainability and how that can be achieved using different tools at different stages of the oil and gas (O&G) exploration. The study introduces a digital well planning solution that estimates carbon footprints for the entire well, enabling real-time emission assessment and optimization during design. The analysis of two planned wells identifies significant emissions from drilling, cementing, and casing activities. This data allows for cost-effective, well design adjustments, contributing to emission reduction objectives. The presentation of data in measurable charts aids compliance with regulations and enhances industry-standard emissions measurement. The integrated platform breaks down silos and enables proactive environmental sustainability efforts.
Optimizing Managed Pressure-Drawdown Flowback for Shale Gas Well with Complex Fracture Network with Fracture Closure and Two-Phase Flowing
Authors: Wang Junlei , Wei Yunsheng 
Published: February 2024

Abstract
Shale gas reservoir is fractured formation with hydraulically fracture network surrounding the shale matrix. Two-phase (water/gas) flowback schedule of fractured well is designed without a sufficient understanding that how the BHP-drawdown the well productivity. A two-phase coupled model is established to simulate the transient gas- and water-production from complex fracture networks. In this work, a new model was established to account for unique transport mechanisms. Different properties of flow mechanisms are assigned to fracture-network domain, stimulated-reservoir-volume (SRV) domain, and non-SRV domain. SRV is characterized by primary- and secondary-fracture network with different propped conductivities along horizontal wellbore. Non-SRV is described by several sets of isolated discrete fractures associated with dual-porosity system. The model is solved by numerical approach for performance forecasting. Embedded discrete fracture modeling (EDFM) and black-oil simulator are used to improve the computational efficiency. By using the numerical model, an efficient framework is established to obtain the optimum flowback scenario based on EUR maximization by using high-dimensional parameter design of experiment. The results show that the effective conductivity deteriorates with the decreases of pressure and water saturation in fracture network during two-phase flowback. The optimum flowback strategy enhances the peak of gas production rate and diminishes the dewatering time simultaneously. Meanwhile, the stress sensitivity contributes to the decreasing of network conductivity, and a more conservative drawdown is suggested for the fracture network with more stress-sensitive conductivity.
Closed-Loop System in Land Drilling Rig
Authors: Alharbi Magbel , Motawee Ibrahim , Albinali Mohammed 
Published: February 2024

Abstract
Closed-loop system in land drilling rig are analyzed in this paper, which considers a first practice "no waste pit". The focus is on the skip-and-ship method for drilling cuttings disposal and excess drilling fluid management. By examining the design, implementation, and best practices of the recycling system, the study aims to enhance waste management, reduce environmental impact, and optimize drilling operations for improved safety and cost-effectiveness.
The study will experimentally investigate the impact of closed-loop system in land drilling rig as an alternative to conventional drilling methods that cause environmental issues. This study evaluates a closed-loop system's effectiveness in managing drilling waste, its environmental impact, safety and cost. The goal is to promote sustainable drilling and reduce environmental harm.
The experimental investigation of closed-loop system in drilling rig demonstrated significant waste management improvements, achieving 100% restoration of a 9,285 ft well with six sections. A dry location with no waste pit, 263 skips transported 1,709 tons and 5,786 BBLs of waste drilling fluid, including harmful oil-based mud. Drilling fluid consumption reduced by 6%, and the system led to zero spills, highlighting its potential to minimize environmental impacts.
The closed-loop system effectively managed drilling waste. Integrating skip-and-ship methods for drilling cuttings disposal and waste fluid management provided robust and efficient waste reduction and restoration. By eliminating spills, the system mitigated environmental risks, improved safety and cost-effectiveness, saving cost from skip-and-ship costs needed for two waste pits. Recycling 63% of waste mud was achievable with the closed-loop system.
Closed-loop system in drilling rig offer immense potential for waste restoration, reducing environmental impacts, and maintaining zero spills. Implementing closed-loop system and optimizing waste management practices can lead the drilling industry towards sustainable and environmentally responsible operations. The study emphasizes the importance of ongoing research and development in closed-loop technology, paving the way for further advancements in drilling waste management, environmental preservation, and operational efficiency.
This paper presents novel insights into closed-loop system in drilling rig, emphasizing their potential to eliminate waste pits and spills through skip-and-ship methods for cuttings disposal and recycling opportunities. Highlighting environmental, safety, and cost benefits, the study explores challenges and future trends, advancing the industry's comprehension of sustainable drilling practices. The paper promotes the broader adoption of closed-loop system as standard rig equipment.
Calcium Sulfate Scale Inhibitor: Does the Carbon Backbone Length Matter?
Authors: Albaiz A. , Almubarak T. , Alissa F. , Owais A. , Aljeaban N. 
Published: February 2024

Abstract
Calcium sulfate (CaSO4) scale precipitation is a challenge faced in the oil and gas industry where it can cause a variety of issues that lead to productivity decline. Amino-phosphonate-base scale inhibitors are used to prevent this type of inorganic scale and have shown great success in the industry.
A common misconception is to believe that high molecular weight amino-phosphonates perform better than their low molecular weight counterparts. This study systematically compares performance of scale inhibitors which have the same number of functional groups but different molecular size and backbone chain length. The study shows the influence of changing the molecular size and backbone chain length on the inhibition efficiency.
Two amino-phosphonate-based scale inhibitors are tested in this work: Ethylenediamine tetramethylenephosphonic acid (EDTMP) and Hexamethylenediaminetetramethylene phosphonic acid (HDTMP). These inhibitors have the same number of functional groups, but they differ in the length of the carbon backbone chain. The inhibition efficiency of each inhibitor is measured through its ability to prevent formation of CaSO4 in a brine containing up to 6,000 ppm calcium ions (Ca2+) and an equivalent amount of sulphate ions (SO42-). Moreover, the remaining concentration of Ca2+ in the solution is measured using Inductive Coupled Plasma (ICP). The results of the study shows that the inhibitor molecules with shorter chain length, EDTMP, have higher inhibition efficiency than the ones with longer chain length, HDTMP. That is because a small dose of EDTMP can efficiently inhibit CaSO4 precipitation while a big dose of HDTMP to do the same job efficiently. Environmental scanning electron microscope (ESEM) is employed to study the effect of the inhibitors on the morphology of the formed scale. The morphology of the formed scale after using the low doses of the inhibitors are investigated by Environmental Scanning Electron Microscope (ESEM), and the resulted images show that the CaSO4 precipitates exhibit deformed shapes compared to the CaSO4 precipitates where no inhibitor is used.
Characterization of Induced Fractures in Carbonate Formation Using Multi-Frequency Dielectric Technique
Authors: Alsamadony Khalid , Al-Ofi Salah , Abdallah Wael 
Published: February 2024

AbstractThe multi-frequency dielectric tool is commonly used to estimate water-filled porosity, water salinity, and rock texture. These are estimated from interpretation (petrophysical) models that analyze the dielectric and conductivity dispersions. Previous studies used dielectric permittivity simulators to characterize rock fractures from digital rock models. However, there is no experimental work has been done to characterize fractures from multi-frequency dielectric measurement and validate the simulation results.In this study, dielectric measurements (coaxial probe) were utilized to characterize the geometry of the induced fractures in calcite samples. The dielectric measurements of the samples were acquired before and after inducing the fractures. These fractures were drilled with different diameters and lengths. Also, fractures geometries and locations with respect to a measurement reference are investigated. Afterwards, the dielectric dispersion data were analyzed and correlated with fractures geometry to derive a mathematical model for fractures geometry (aspect ratio) prediction.In the results, after controlling potential factors that affect dielectric dispersion, it is observed that the location of the induced fracture affects the dielectric dispersion. This may hinder the dielectric sensitivity to fractures with different diameters. Although dielectric measurements are more sensitive to the change in fracture length, they could be limited by the depth of the investigation. Based on these observations, several correlations are presented for the fracture aspect ratio of the studied samples. These correlations use the slope and average values of the dielectric and conductivity dispersions at a specific frequency range.This work experimentally demonstrates the sensitivity of the dielectric and conductivity dispersions to fracture geometry. Digital rock models of the studied samples could be developed. Thus, the results of this work may be utilized to calibrate and validate dielectric permittivity simulators to match the actual measurements. Consequently, the need for laboratory measurements could be reduced.
A Simple Yet Impactful Innovation to Optimize Production of Low-Quality Reservoir (LQR) by Using a Modified Venturi Choke, Pilot Case at Matured Waterflood Field Bravo, Central Sumatera Basin
Authors: Fadli Ade , Rahman Aulia , Putranto Daniel Hadi , Dewi Cintani Kusuma , Nurjaman Muhammad Saeful , Ramadhan Iftikar Luthfi , Afton M. 
Published: February 2024

Abstract
In a mature asset like Bravo field in Central Sumatera Basin, the ‘easy to produce’ oil is becoming increasingly rare and hard to find. Therefore, pursuing oil at the low-quality reservoir (LQR) has become one of the main focuses nowadays. Despite having huge potential due to its low recovery nature, optimizing LQR production comes with set of challenges. This paper highlights a successful innovation to unlock the LQR potential, offering a solution to maximize production.
The innovation involves the application of a modified venturi choke (VC). Basic principle of this method is producing the LQR zone (low rate, low watercut) with the assist from a better-reservoir quality zone below, namely High-Quality Reservoir (HQR) zone (high rate, high watercut). Unlike the conventional commingle approaches, the modified VC is strategically placed between the zones, applying fluid restriction to the HQR zone. Acting as a downhole choke, it induces a substantial pressure drop, resulting in a jetting effect that efficiently strips out fluids from the LQR zone, thereby enabling optimal oil production contribution.
Pilot execution on the first 2 wells in Bravo Field successfully delivered 100 BOPD incremental oil gain, proven that this newly developed method is working very well. The installation of the venturi choke (VC) has led to a substantial improvement in oil contribution from the LQR zone, a fact confirmed through oil finger printing analysis. Notably, the LQR zone, which was theoretically unable to produce even with the smallest pump and would not contribute significantly through conventional commingle methods, has demonstrated its production potential using this approach. The established flow process and screening criteria are also proven effective to capture potential candidates that cannot be produced with traditional commingle methods. Comprehensive analysis of historical production data, swab tests, G&G interpretation, reservoir simulation, and well modeling played a pivotal role in selecting the most suitable LQR candidate for this optimization. Additionally, considering VC material is available at relatively large quantities on hand, makes it feasible to implement the same approach in numerous other LQR potentials within the field and the surrounding region. This scalability further highlights the benefit of this method in unlocking LQR potential beyond the initial pilot wells.
Innovative Water Conformance Solution Led to Enhanced Well Performance
Authors: Murtaza Shoaib , Madan Mohammed H 
Published: February 2024

Abstract
Over the years, the oil and gas industry has mastered and perfected a range of techniques to shut-off undesirable water production or to minimize it. Mechanical and chemical water-shut-off techniques produced the desired results and are still in use. Chemical water-shutoff has evolved over time with many novel chemicals/products entering market.
Advanced water conformance solutions have recently come into existence in the form of sophisticated downhole completions like inflow control devices (ICDs) – both passive and active, water adaptive/responsive ICD screens, surface controlled smart completions, and so on. All these completions have their own limitations and challenges.
The paper explains a novel water conformance process for wells equipped with shiftable ICDs with open hole packers for compartmentalizing the reservoir section based on open hole log interpretation and formation characteristics. To maximize the chance of job success, careful evaluation of completion and production is a must before deploying a coiled tubing (CT) conveyed shifting tool to shift open/close various ICDs. To accurately perform and record ICD shifting events, a stroker is deployed as part of the bottom hole assembly (BHA). Before deciding on the final ICDs to be shifted, a suite of production logging tools (PLTs) and noise logging are run. Based on the outcome of the logging job, the final dispositions of ICDs are decided. Stroker's current signature confirms the ICD shifting process at surface. Noise logging is used to confirm the integrity of open hole packers. The method resulted in sustaining well performance and concomitant decrease in water production.
This paper describes detailed job planning, field data interpretation process, decision making and some key insights for enhancing the whole work process.
Method to Identify Perforation Locations for Fracturing Deep and Tight Gas Reservoirs
Authors: Xia K. , Wang W. , Cui Y. 
Published: February 2024

Abstract
Fracture initiation has been a challenging issue for fracturing deep and tight gas reservoirs, which generally requires a high breakdown pressure for hydraulic fracturing treatment. In this situation, fluid injection has to terminate at the very beginning. Toward predicting and solving this issue, a novel fracturing system for deep and tight sandstone gas reservoirs was developed. Other issues related to perforation cluster layout design will be discussed as well. The key components of the fracturing system and some criterion will be introduced in this paper, which can be used to identify the ideal perforation locations along the landing part and select the right perforation strategy accordingly. The main components of the fracturing system include: (1) Evaluating the log-based diagenetic rock typing and flow index; (2) 1D mechanical earth model; (3) calculating the breakdown pressure envelope along the well trajectory of the landing part; (4) calculating the optimal perforation directions along the landing part; (5) select the first set of perforation locations based on the log-based diagenetic rock typing and flow index; (5) narrow the first set of perforation locations to a second set of perforation locations based on the breakdown pressure envelope; and (6) compare the breakdown pressure envelope of the second set of perforation locations to a maximum downhole pressure the used wellhead can safely provide to determine a perforation strategy. The computational framework to calculate the breakdown pressure envelope and optimal perforation directions is applicable to arbitrary well trajectory. The fracturing system has been used to provide pre-fracking support for wells that landed in deep and tight sandstone reservoirs, which can assist in selecting locations with good rock typing and relatively low breakdown pressure. Also, it can indicate whether oriented perforation should be used. By taking these efforts and procedures, the fracturing success rate for deep and tight gas reservoirs can be improved, which has been verified in practice. Example studies from the field will be provided to demonstrate the fracturing system's performance and applicability.
Real Time Petrophysics via Artificial Intelligence in Brown Field Development
Authors: Shah Jamari Mohd , Sansudin Salmi , Fadhil M Imran M , Gazali Ismail Marzuki , Zakeria Ahmad Fakrudin , Husni Husiyandi 
Published: February 2024

Abstract
The paper introduces a novel approach to evaluate well log data in real time during downhole data acquisition. This approach has been successfully implemented in multiple drilling projects. It relies on effective real-time data transmission with the key enabler of the system is development of the well log artificial intelligence module. Time is of the essence during drilling operations. Hence, any efforts towards increasing the operation efficiency can lead to a safer and more optimized well delivery. A machine learning application for real-time petrophysical evaluation during drilling was successfully developed to achieve this ambition. The application which named Well Log Data Artificial Intelligence was tested in a Malaysia complex brownfield infill drilling project, where it proved to promote a seamless decision-making process during drilling and simultaneously lead to financial and operation value creation. The application uses selected key wells in the field as training dataset before the actual drilling operation. Random Forest ensemble was utilized for model learning and correspondent petrophysical evaluation, The module can predict reservoir characteristics in real-time by leveraging on feeder open hole raw curves as inputs with integration of existing trained model and real time data transmission. Moreover, the application provides easily accessible prediction results through the same display interface as the real-time data transmission. This makes it attractive for multi-disciplinary utilization during discussion.