bluuebunny/crossref_metadata_2025 huggingface dataset:
Sustainability of Small-Scale Capture Fisheries Based on Coastal Vulnerability in Pangpang Bay, Banyuwangi Regency, Indonesia
Authors: Setyaningrum Ervina Wahyu , Sambah Abu Bakar , Wiadnya Dewa Gede Raka
Published: November 2024

Graphical Abstract

Highlight Research

Climate change impacts on coastal vulnerability.
Low coastal vulnerability in Pangpang Bay, Banyuwangi Regency.
Sustainability of small-scale capture fisheries based on vulnerability.
Sustainable small-scale fisheries management.

Abstract
Teluk Pangpang is one of the water areas that has considerable capture fisheries potential in Banyuwangi Regency, Indonesia. On the other hand, climate change impacts the vulnerability of coastal areas and coastal communities, especially small-scale fishers. This study aims to analyse the coastal vulnerability of Pangpang Bay and formulate a sustainable development of small-scale capture fisheries in Pangpang Bay. The research method used a descriptive method with a quantitative approach. Data collection techniques used geographic information systems and focus group discussions (FGDs). The data analysis used was Coastal Vulnerability Index (CVI) analysis with spatial approach and Participatory Prospective Analysis (PPA). From the CVI analysis, through the assessment of geomorphological parameters, erosion/accretion, coastal slope, distance of plants from the beach, wave height, and average tide range, the level of coastal vulnerability of Teluk Pangpang is included in the low category. Meanwhile, the PPA analysis resulted in seven variables that most influence the sustainability of small-scale capture fisheries, namely climate change, coastal vulnerability, coral reef area and density, number of small-scale fishers, catches, human resources of small-scale fishers, and management of small-scale fisheries resources. Furthermore, for the formulation of the sustainability scenario of small-scale capture fisheries in Pangpang Bay, is to minimise the impact of climate change and conduct disaster mitigation, improve the human resources of small-scale fishers, and equalise perceptions as outlined in the commitment between all interested parties and small-scale fishing communities.
Analysis of sildenafil citrate in male stamina herbal medicines from the Magelang region, Central Java using thin-layer chromatography and UV spectrophotometry
Authors: Saputra Ilham Fahmi , Haresmita Perdana Priya , Dianita Puspita Septie , Kholifah Eva
Published: November 2024

Background: Male stamina herbal medicines are widely consumed in Indonesia, often believed to enhance sexual performance. However, the illegal addition of medicinal chemicals (BKOs) such as sildenafil citrate in traditional herbal products poses health risks.
Objective: To identify and quantify sildenafil citrate in selected herbal medicine samples using thin-layer chromatography (TLC) and UV spectrophotometry.
Method: Three samples of male stamina herbal medicine were purchased and subjected to organoleptic tests. Ethanol (96%) was used for extraction, followed by TLC analysis using two mobile phases (methanol: chloroform at 4:1 and 1:1 ratios). UV spectrophotometry was employed to determine the maximum absorbance wavelength and quantify sildenafil citrate.
Results: TLC analysis revealed that two samples (K and L) contained sildenafil citrate, with Rf values consistent with the standard. UV spectrophotometry confirmed the presence of sildenafil citrate at a maximum wavelength of 292.5 nm. Sample K contained 0.96%, while sample L had 13.766% sildenafil citrate.
Conclusion: The presence of sildenafil citrate in two samples violates Indonesian regulations prohibiting medicinal chemicals in herbal products, raising significant safety concerns.
Antifungal activity of shampoo formulated with water spinach (Ipomoea aquatica) ethanolic extract against Pityrosporum ovale
Authors: Aisali Ledyta Asa , Genatrika Erza , Budiman Arif
Published: November 2024

Background: Dandruff, primarily caused by Pityrosporum ovale, is a common scalp disorder, especially in tropical regions. Natural alternatives, such as water spinach (Ipomoea aquatica), are increasingly being explored for their antimicrobial properties due to their minimal side effects.
Objective: This study aimed to formulate an anti-dandruff shampoo using ethanol extract of water spinach and evaluate its physical properties and antifungal activity against P. ovale.
Results: The phytochemical screening of the water spinach extract confirmed the presence of polyphenols, flavonoids, and quinones, known for their antimicrobial properties. The shampoo formulations met pH and foam height standards and remained organoleptically stable over 28 days. However, viscosity decreased below the standard (<400 cps) after 28 days. The 4% extract formulation (F3) showed the highest antifungal activity with an inhibition zone of 10.01 mm, significantly greater than the negative control (p<0.05).
Conclusion: Water spinach ethanol extract can be successfully formulated into a shampoo that meets most physical requirements and exhibits antifungal activity against P. ovale. The 4% extract formulation demonstrated the highest effectiveness, though viscosity stability requires further optimization.
In silico analysis of quercetin and its derivatives as potential TRPC6-targeted treatments for diabetic neuropathy
Authors: Pangestu Maryo Adjie , Auli Winni Nur , Saputro Anjar Hermadi , Pasaribu Romualdo , Maharani Gita Putri , Yunita Nadia Rahma , Choiriah Ika Putri , Ainun Hadhistia Nur , Erniningsih Ni Ketut , Andini Citra
Published: November 2024

Background: Diabetic neuropathy is a condition that arises as a complication of diabetes mellitus and often causes pain in patient. Quercetin and its derivatives have antinociceptive activity, making them potential agents for relieving the pain associated with diabetic neuropathy.
Objective: This study aims to analyze the interactions between quercetin and its eight derivatives with canonical transient receptor potential channels 6 (TRPC6) as protein target.
Method: The TRPC6 structure (PDB ID: 6UZ8) was prepared and validated with redocked to native ligand R0D using Autodock 4.2.6, with the established grid box and grid center settings. The test compounds were then optimized and docked using the same grid box and grid center settings as in the validation process, followed by visualization and analysis of the docking results.
Results: The compound with the best affinity for TRPC6 was tamarixetin, with a binding energy value of -3.27 kcal/mol, close to the binding energy value of the native ligand, which was -4.22 kcal/mol. The amino acid residues interacting with tamarixetin at the active site were 702-Asn, 705-Tyr, 706-Val, and 709-Gly. This indicates that tamarixetin and the native ligand bind to the same active site amino acids, resulting in a similar affinity to the native ligand in inhibiting TRPC6.
Conclusion: A total of eight quercetin derivatives were predicted to have TRPC6 antagonistic activity against diabetic neuropathy, with tamarixetin exhibiting the highest affinity compared to the other quercetin derivatives.
Time Framing and SDGs: Can Imaginary Future Generations Alter People’s Perceptions and Attitudes?
Authors: Uwasu Michinori ,   Editorial Office, Kuroda Masashi , Fuchigami Yukari , Hara Keishiro
Published: November 2024

This study verifies the effectiveness of Imaginary Future Generation (IFG) in promoting the Sustainable Development Goals (SDGs). Using data from an online survey, we calculated sustainable development component measurements to assess the understanding of SDGs and demonstrated whether IFG can influence futurability components. Statistical analysis shows that knowledge significantly impacts people’s attitudes towards SDGs, with informed individuals more likely to cooperate in addressing these issues. Comparing the treatment and control groups revealed that participants asked to envision themselves as residents of 2050 (IFG) better grasped the essence of Agenda 2030 and exhibited more cooperative attitudes toward sustainability. Regression analysis confirmed these effects after controlling for individual attributes and SDG knowledge. The study finds that while raising awareness is crucial, IFG makes people perceive sustainability problems as personal concerns. IFG enhances respondents’ futurability, encouraging positive attitudes and long-term thinking. Additionally, IFG promotes participation, inclusive ideas, and increased SDG knowledge.
Credentials for Tomorrow: Micro Neuro Mesh-Based Curriculum Innovations in Petroleum Engineering
Authors: Samuel Robello
Published: November 2024

The transition from the conventional "book smart" paradigm to a more adaptable educational model is imperative in response to evolving industry demands. This study explores the integration of micro-neuro mesh-based credentials into petroleum engineering curricula, aiming to offer flexible learning pathways. By advocating for simplified accreditation procedures and a centralized platform for approved micro-credentials, the research addresses the evolving needs of both education and industry, facilitating effective curriculum design and implementation. The petroleum engineering industry is undergoing significant transformations driven by advancements in technology, evolving market demands, and an increasing emphasis on sustainable practices. Traditional education models must adapt to these changes to effectively prepare graduates for the future. This paper explores the integration of a micro-credentials-based curriculum into petroleum engineering education, offering a flexible, skills-focused approach that aligns with industry needs and enhances student employability.
A Novel Approach to Predict Permeability in Non-Cored Wells and Establish Reservoir Rock-Types in Complex Carbonate Reservoir Using Pore Geometry Structure (PGS): Integrating Petrophysical Properties and Diagenesis in Lower Cretaceous Carbonate Reservoir of Abu Dhabi, UAE
Authors: Kusuma Didit Putra , Farooq Umer , Alsabeai Jawaher , Al Shamsi Latifa , Montani Hiroki , Alshamsi Suad , Makishima Ken , Akbar Muhammad Nur Ali
Published: November 2024

The primary aim of our study was to introduce and validate the Pore Geometry Structure (PGS) approach for predicting permeability in non-cored wells and establishing reservoir rock types. To ensure consistency, this novel method was benchmarked against traditional core-derived permeability measurements and an existing machine learning method (K.mod module).

PGS utilizes a constant cylindrical capillary pipes model as the dependent variable, integrating tortuosity and similarity exponent as independent variables to represent complexity. The study analyzed data from four cored wells, totaling nearly 1650 feet, which included 1185 routine core analysis (RCA) samples, 440 mercury injection capillary pressure (MICP) samples, and thin section data. These datasets were quality-checked and used to classify rock types by linking petrophysical groups (PGs) to geological features.

Nine PGs were identified for limestone and six for dolomite facies based on MICP parameters, pore throat radius, and the porosity-permeability (phi/k) relationship. The phi/k data were plotted on a PGS diagram, establishing a relationship between pore geometry and structure, as delineated by different line gradients. This analysis resulted in eleven PGS-based rock types with distinct constants. The PGS rock-typing method demonstrated effective clustering, complementing PGs in defining diagenetic processes such as cementation and dissolution. Contingency analysis confirmed a strong correlation (70%) between PGs and PGS rock types.

Furthermore, the PGS method's permeability predictions are closely aligned with core data, with 80-90% of predictions falling within the core-derived range. Compared to the K.mod method, the PGS approach exhibited a superior correlation in permeability prediction. This paper outlines a step-by-step process for independently calculating permeability predictions and defining rock types using the PGS approach in complex carbonate pore systems.

Our study highlights the practical implications of the PGS approach in complex carbonate reservoirs. It significantly improves precision and reduces uncertainty in permeability predictions for non-cored wells. The PGS rock-typing method also offers an integrated workflow that links diagenetic processes to PG classification, thereby enhancing reservoir characterization.
A Design-Driven Approach to Emissions Quantification through Digital and Domain Integration
Authors: Khan Abdul Muqtadir , Menasria Samir , Drews Timothy , Bannikov Denis , Sukumar Dinesh , Teoh Melissa
Published: November 2024

The energy industry has been taking transformative actions to achieve sustainable growth. Specifically, hydraulic fracturing and associated activities are known to be emissions intensive. The objective here is to develop a digital tool that enables quick, efficient, error-free carbon dioxide (CO2) emissions footprint assessments for various job types. The workflows implemented in the tool cover different phases in the intervention and stimulation life cycle of a well.

The application's architecture is composed of generic modular assessments, such as resource utilization, site execution, and post-job activities. The user experience focuses on simple domain workflows in which complex processes are embedded to automate the corresponding emissions calculations. Detailed emissions factors for different fuel types are utilized from US Environmental Protection Agency (EPA) data. The engine first identifies the baseline fuel consumption related to product transportation, equipment mobilization and demobilization, execution at wellsite, and related well cleanup or flaring. The baseline uses historical consumption data, but it goes through a calibration loop based on real-time consumption data tracking. With the emissions factors and fuel efficiency, the second step of the engine is to calculate the CO2 emissions related to the fuel quantity and type. The tool incorporates eight different fuel types and multiple publicly available gas compositions from various basins.

The application organically integrates with expansive master data systems such as fluid, proppant, and equipment databases. Moreover, users can seamlessly import design details in one click from other stimulation and intervention design software. Multiple workflows can then be generated to sensitize fluid volume, proppant mass, job type, fuel type, technologies, digital innovations, etc. The current interface captures detailed workflows for conventional and unconventional operations in land and offshore environments. It also supports utilization of an electric fleet. With this digital solution, we are well positioned to (1) accelerate the decarbonizing initiative and (2) position new technology portfolios to transition to cleaner operations. Current implementation showed the impact of technologies such as channel fracturing, retarded acid systems, degradable chemistry, and various predictive models and is positioned to enable smart strategies by integrating sustainability assessment and metrics to drive business growth. Real cases from some geographies show enablement of 20 to 30% emissions reduction.

This novel effort is now extended to collaborate with engineering and supply chain teams for real-time measurements, post-job actual emissions calibration, and embodied carbon of material to measure accurately the path to net zero.
Application of a Novel Solids-Free Diverter as an Alternative and Efficient Option to Replace Straddle Packers to Maximize Acid Coverage and Reduce Workover Rig Cost and Intervention Time: Two Case Studies from Iraq
Authors: Tellez J. R. , Doghmi A. , Alarcon X. , Corrales J. , Chuc E. , Masoodi A. , AI ledani K. , Nuñez M. Ramirez , Alvarez J. , Shareef B.
Published: November 2024

The use of straddle packers is a common technique to accurately direct fluid treatments to specific wellbore areas. Once the packers are set, fluid is pumped through the inner diameter of the tool to stimulate the isolated zone between the packers. However, their use can be associated with additional costs, potential downhole tool failure, additional slickline and multi-finger caliper runs, and nonproductive time (NPT). Relative permeability modifiers (RPM) are a cost-effective diverter option to reduce rig and associated equipment costs through the provision of a high diversion-pressure response throughout stimulation treatments.

A field application of a novel solids-free acid diverter (SFAD) system based on the use of RPM technology throughout the stimulation of sandstone formations in Iraq is described. This application used a solutions-oriented software package for complete remediation and stimulation. This novel SFAD decreases matrix-relative permeability to water-based fluid with the use of an ionic polymer, which directs subsequent stages to untreated zones. The water-based acid stages are then forced to other zones, which improves the acid coverage.

This low-viscosity (less than 4 cp) RPM withstands high salinities and adheres immediately to the rock surface, which reduces soak times and makes the polymer suitable for continuous pumping. No special treatment considerations are necessary for this SFAD; it is simply pumped between the acid stages.

SFAD can be used in carbonate and sandstone formations. Two recent treatments performed in a sandstone formation in Iraq that exhibited pressure increments up to 1,000 psi while the diverter was pumped are the focus of this work. The total acid volume was ramped up in two stages with 40/60 diverter ratios.

More than 20 treatments have been performed in Iraq in carbonate and sandstone formations with this novel SFAD. The RPM, recently introduced to optimize well interventions, has demonstrated efficiency in intervals up to 50 m and permeability up to 6 Darcys.
Selecting Injected Viscosity in Polymer Flood Projects: A Controversial and Critical Question
Authors: Delamaide E.
Published: November 2024

Polymer injection is now a mature EOR process, and numerous large-scale expansions are currently underway while new projects are being designed all over the world. Curiously, one of the basic design questions still remains highly controversial: what is the optimum viscosity that should be injected? Some practitioners advocate injecting very high viscosities while others advocate just the opposite. The selection of the viscosity to inject has obvious economic implications as it is directly linked to the polymer concentration and thus to the cost of the polymer which can reach tens or hundreds of millions of dollars for large expansions. This paper will explain why the question still remains without a clear answer and will describe the arguments of both camps while outlining the pros and cons of each approach using case studies.

The paper reviews the theoretical and practical arguments based on real field experience to help future project designers select the right viscosity for their polymer project. This is a critical issue as this can have an impact on injectivity and economics.

The Gogarty method is a theoretical tool to select polymer viscosity, but it is extremely conservative and may lead to over-design. Reservoir simulations have also been used in several cases to justify extremely high polymer viscosities but in some cases field results do not bear out these expectations. The conclusions of this work show that several factors need to be considered when selecting polymer viscosity; beyond injectivity and mobility control which are obvious ones, another important factor is the reservoir layering. Field experience shows that in single layer reservoirs such as those in Canada, lower viscosities can be used but that in cases of heterogeneous, multi-layer reservoirs, higher viscosities are required. However, theory demonstrates that even when injecting infinite polymer viscosity, vertical sweep will remain controlled by the permeability contrasts. Finally practical concerns for expansions should not be forgotten: practical experience in Daqing for instance shows that injecting at high viscosity can cause severe casing and vibration issues, while theory and practical experience in other fields both confirm that produced polymer concentration could cause severe issues in the surface facilities.

Reservoir and surface aspects need to be considered with the view that even when designing a pilot, large-scale expansion is the ultimate goal that needs to be kept in sight. Expansions require not only successful pilots but also attractive economics and will present challenges beyond those experienced in a pilot such as separation issues in the surface facilities. The paper will provide some guidance for the design of their future projects and provide the context for making such decisions in the framework of large-scale field projects.
Machine Learning-Driven Prediction of Density and H2-Brine Interfacial Tension: Implications for Underground Hydrogen Storage
Authors: Janjua Aneeq Nasir , Patil Shirish , Kamal Muhammad Shahzad , Ali Muhammad , Tariq Zeeshan
Published: November 2024

Underground hydrogen (H2) storage presents a viable way towards energy transition and meeting the growing energy demand. To achieve the net-zero target and mitigate anthropogenic greenhouse gas emissions, the contribution of H2 as a clean energy source has proved to be an efficient alternative for future use. Interfacial tension (IFT) is a paramount parameter that influences the displacement of H2 and its storage capacity in geological conditions. This paper aims to accentuate the storage of clean H2 at a large scale and leverage robust machine learning algorithms to predict the IFT of H2-brine systems at various thermophysical and salinity conditions.

In this study, predictions of brine density and IFT of H2-brine systems are performed using input features, including, pressures (0.1, 5, 10, 15, and 20 MPa), temperatures (25, 50, and 70°C), and salinities including deionized water, seawater and brines of 1 molar and 3 molar concentrations for various salts (NaCl, KCl, MgCl2, CaCl2, and Na2SO4) from our experimental data. Extensive experimental measurements are recorded and a dataset consisting of 180 data points is utilized. Three robust machine learning techniques, viz., gradient boosting regressor (GBR), extreme gradient boosting (XGBoost), and random forest regressor (RF) are employed to predict the brine density and IFT of H2-brine systems.

Various statistical techniques are employed to initiate this process, and histograms of the input and output parameters are generated. The correlation heat maps are populated with Pearson's correlation coefficient for density and IFT prediction. The relative importance of input parameters with IFT data of H2-brine systems is determined by Pearson, Spearman, and Kendall models. Evaluation of the machine learning results indicates a high prediction accuracy with RF and XGBoost algorithm with a coefficient of determination (R2) value of 99.9% for training and 99.5% for testing data. Root mean square error (RMSE) and mean absolute error (MAE) are subsequently determined.

The findings from this study demonstrate the remarkable accuracy of machine learning algorithms in predicting the density and IFT of H2-brine systems. This study can be effectively utilized further to evaluate the displacement of H2 and storage capacity, reducing the time and cost associated with determining IFT with traditional methods.
Advanced Gas Analysis Meets Geoscience Solution in Norway Field: The Insights of a Holistic Approach
Authors: Arcano N. S. , Vicuna B. , Criollo D. , Caldas P. F. B. , Donnadieu S. , Inversen M. , Ungar F. , Odeh P. R. , Bravo M.
Published: November 2024

Equinor has a complex faulted field in Norway with expected different fluid contacts. To maximize the reservoir understanding a geoscience approach is applied for this project. The utilization of Ultra Deep Azimuthal Resistivity (UDAR) technologies is typically sufficient to control the vertical and lateral limits of a reservoir and unveil potential flooded intervals and oil water contacts (OWC). However, the differentiation between oil and gas by just LWD and UDAR data is not possible. This study demonstrates three geoscience areas contributing for early decision making while drilling the Brent Group formation.

The cost-effective solution in this project was the implementation of advanced mud gas (AMG) using a constant volume and constant temperature (CVCT) extractor with advanced gas chromatograph to analyze species such as methane to octane. Correction for recycling gas and extraction efficiency correction (EEC) of methane to pentane species were also applied in real time (RT). The gas ratios curves were the first look of the PVT for this well, therefore the gas oil ratio (GOR) prediction based on the model proposed by Yang et al., 2019 were also available and provide reservoir insight while drilling.

The High-Resolution ultrasonic image tool was used to detect bedding, fractures and faults planes post-drilling, and in conjunction to UDAR results several diagrams such as Stereonet plot and curtain sections were displayed. Additionally, an ultrasonic caliper tool was used to identify the borehole shape. The sandstone bedding plane orientation showed several trends inside the whole interval and most of these changes were associated with faulted intervals and validated with Geosteering inversion model. The fault system understanding is important in this basin since it contains a western graben created by several faults stepping down preserving Upper Brent.

Petrophysical analysis complements and supports the results from AMG, UDAR and borehole image analysis. The basin setup is helpful to understand the fluid distribution in the petroleum system. From a petrophysical viewpoint, water saturation from resistivity logs and neutron-density separation helped to estimate fluid types, and it was validated with AMG. The identification of 300m of water flushed zone, later confirmed by production, shows the holistic methodology implementation allowed a review of the fluid distribution in the well results. This paper demonstrates the contribution of the race to digital transformation and enabled reservoir characterization while drilling.
Using advanced technology to develop complex Northern Kuwait Jurassic Gas (NKJG) reservoirs to unlock additional reservoirs potential.
Authors: Al Saleh A. , Sabti A. , Al-Anezi H. , AlJasmi S. , Abas F. , Emera M. , Taheri S. , Nishi K. , Khakmedov Azat , Ameer A. , Al Saffar A. , Al-Ajmi A.
Published: November 2024

Field Development Plan (FDP) of the North Kuwait Jurassic Gas (NKJG) asset in Kuwait served as the basis of the yearly asset action plan, future development wells, development options and production forecast. Due to nearly fourfold increase in gas offtake and the increased number of wells, new production challenges, ongoing appraisal results from the deeper contact area, it was decided to update FDP based on the new data/challenges and using the new technologies.

In a modified version of Shell's standard Opportunity Realization Process (ORP), a phased approach for developing fields is applied. The NKJG asset approach to this standard ORP process is different in two ways: – The pace of development/activities is very high, driven by gas demand– Concurrent appraisal, development planning, execution activities, and operation of the fields

The FDP work was carried out by an integrated, multi-disciplinary team consisting of KOC, SLB and Shell

staff. A number of new technologies have been applied to solve current production issues.

The results for this work comprise of: – Base case depletion drive development plans with the updated well count for each reservoir.– Production forecast for all potential, current and future development wells (different well types based on reservoir conditions/properties) was delivered.– Development decisions like compression, artificial lift (AL), velocity string and well types (multistage frac, multi-lateral) are also addressed in this FDP update.– Gas recovery factor has increased as the very low pressure (VLP) compression was introduced in this work.– Additional gains because of better drainage, longer production period and VLP.

This work presents some of the new technologies which enhance oil and gas production and solve development challenges in complex tight carbonate, highly fractured HP/HT reservoirs, sour near critical fluids, in a congested surface area fields. Examples from these technologies are multilateral wells and different types of wells, CO2 energized and multistage frac stimulation, AL, and VLP. Integrated work has been done using dual permeability modelling system to test impact of different technologies on production profile.
From Obstacles to Opportunities: Unlocking the Power of Customized Multilateral Solutions
Authors: Almasri Abdulrakeeb , Alsadeh Adnan , Shukor Arra'uf , Abdulhalim Abdullah
Published: November 2024

The continuous advancement of multilateral completion technology has significantly transformed the oil and gas sector. It has enabled access to reservoirs, resulting in a substantial influence on production capacity. However, the challenges faced when drilling a multilateral well need to be understood and addressed. This paper will outline such challenges and provide insights into how these were overcome to achieve the desired goals.

The efficacy of the Multilateral selective lateral access window has been demonstrated over the past few decades. It has allowed successful identification of reservoir problems and implementation of necessary measures based on obtained data. However, drilling the multilateral and deploying the technology in a challenging formation required extensive planning. The technology required a TAML-4 junction in a formation that encountered heavy losses. This necessitated further planning, such as adjusting the length of the liner and performing off-bottom cementing. All whilst ensuring the lower completion, featuring inflow control devices (ICDs), could be run unhindered.

TAML level 4 junctions require precise planning, orientation, and access. The integrity of the formation is at risk if the liner is not set in the predetermined depth and pumping the cement is not performed precisely. Therefore, the formation where the window will be cut must be consolidated and free of losses. However, if the formation needs to be drilled in an unconsolidated formation with losses expected to be faced while drilling, some engineering solutions must be implemented to ensure the integrity of the formation is not compromised. Identifying the loss zones and the ability to cure or avoid them are key to the success of the operation. Furthermore, the design and procedures can be customized to ensure success. Ultimately, the features of the junction cannot be compromised, and the junction must be of high quality to facilitate further well operations over the life of the well.

This paper will focus on the recent developments in multilateral completion technology, with a special emphasis on the capability to customize the solutions to achieve the objectives of the well.
Successful Deployment of Multiple Inversion Workflows in Low Resistivity Contrast and High Noise Environment
Authors: Thar H. , Valerio R. , Bandyopadhyay I. , Batheyab F. , Mazrouei M. , Deng L. , Soliman A.
Published: November 2024

Reservoir navigation objectives of any lateral is to geosteer in the desired target layer maximizing the productivity and/or injectivity. Target layers with low resistivity bounded by slightly higher resistivity shoulder beds create low resistivity contrast and high noise environment attenuating the boundary detection capability of Deep Azimuthal Resistivity (DAR) tools. This paper presents successful case studies where multiple DAR hybrid inversion workflows were implemented to counter this challenge and optimize production within a field.

Carbonates target layers with inverse resistivity signature and heterogeneity from the offset wells were analyzed and incorporated into a detailed feasibility pre-drill reservoir navigation model which highlighted the challenges due to low resistivity contrast and high noise environments. Workflow parameters were optimized to ensure an effective depth of detection. While drilling, the DAR tool was deployed along with GR, Density, Density image and Neutron Porosity. Multiple hybrid inversion workflows with their optimized parameters reduced the impact of noise in low signal environment and increased the reliability of resistive boundary approach. This successful method was utilized for proactive geosteering in similar wells.

The holistic approach of data incorporation to find targeted solutions in pre-drill phase highlighted the range of parameters to ensure reliable detection capability in the real time. During the drilling phase, optimization of the multiple inversion workflows enhanced resistive layer approach understanding which in turn helped in navigating along the optimum target layer. Heterogeneity in the target zone affected the resistive layer approach capability. The combined data from other sensors and the inversion results integrated into the geosteering workflow helped in taking informed well placement decisions in the complex heterogeneous environment heterogeneity. Upon successful utilization of the DAR technology along with proactive geosteering in the initial wells, this application was taken forward to all upcoming wells with similar target profiles. This Increased the net to gross of the wells compared to the previous wells which were navigated with a reactive geosteering approach.

The limited boundary detection capability of DAR tool due to inverse signature, low resistivity contrast and high noise environment was successfully overcome through the application of optimized hybrid inversion workflows.
Implementing a Solids-Free, Non-Damaging Loss Control Solution to Enable Overbalanced Workover Interventions: Case Studies and Applications from 80+ Wells in Iraq
Authors: Alarcon X. , Doghmi A. , Ahmed M. , Tellez J. , Alvarez J. , Chuc E. , Masoodi A.
Published: November 2024

Controlling lost circulation can be costly and complicated. When well conditions include low reservoir pore pressure and high reservoir permeability, traditional techniques to minimize fluid loss, such as solids or viscous pills, can damage the formation due to interaction with sandstone formation characteristics, such as kaolinite, smectite, incrustations, polymer residues, pH changes, clay swelling, and others. This often means that minimizing near-wellbore damage is key for the future productivity of the well.

This paper presents a laboratory validation and field application of a novel solids-free fluid-loss (SFFL) system based on a relative permeability modifier (RPM) used during well-kill and overbalanced workover operations. This study will focus on the detailed information needed for selection, treatment application, and operational procedures used in sandstone formations in Iraq.

This system relies on an ionic polymer that decreases matrix permeability to aqueous fluids, limiting leak-off into treated zones. This RPM, with low molecular weight, high salinity tolerance, very low viscosity (less than 3 cp), and acid resistance, immediately adheres to the rock's surface, eliminating the need to shut the well in. In addition, this system does not require breakers, which eliminates the negative impact on post-stimulation well productivity. Laboratory test data shows the capability of the material to control fluid leak-off and achieve high levels of regained permeability to hydrocarbons. Fluid is placed in front of the target zone and can be pumped, squeezed (or gravity injected) into the formation. As the majority ofmost of the cases have been applied in old wells, the treatment injection pressure limit must be related to the casing integrity with no more than 1,000 psi measured at surface.

To date, about 80+ jobs have been performed with this novel SFFL system in Iraq. This system has been proposed for solving partial and total losses, to full circulation in overbalanced operations such as: Lost-circulation events during well killing operationsWellhead maintenanceWell integrityReplacement of electrical submersible pumps (ESPs)Overbalanced tubing-conveyed perforating (TCP), among others

Laboratory tests, procedures, case histories, and continuous improvement actions are presented in this study.
A Novel Workflow of 3D Static Modeling Uncertainty in Karstic Reservoirs of the Central Luconia Province, Sarawak
Authors: Trianto A. , Jalil M. A. , Tewari R. D. , Sedaralit M. F. , Hendraningrat L. , Sagar S. F. , Latiff A. H. , G. J. Soto
Published: November 2024

Karst networks are characterized by their complex and heterogeneous dissolution cavities related to the shape, dimension, distribution, and fill, presenting significant subsurface challenges in reservoir characterization and management. In this work, it is proposed to deploy a new methodology to capture geological uncertainties in karstic reservoir while mapping field-wide karst geobody in JTN Field (Luconia). Previous studies assumed that karst geobody remains open as conduits, acknowledging the substantial influence of karst features on reservoir behavior and the flow of fluids. This further becomes an oversimplification of handling karstic carbonate reservoir modeling that may influence the result of hydrocarbon volume in place and reserve estimation, well location optimization, and field's management plan. In this research, we are examining specific seismic characters, i.e., chaotic reflection inside the collapsing cave geobody to identify potential particles filling within the systems. By integrating the chaotic seismic reflection inside collapsed network combined with the architecture of the conceptual model, the individual geobodies checking technique will be applied to identify possible karst fills within the karstic drainage components. This will allow the workflow to further assign possible karst fills and properties within the region with calibration of production performance. The proposed research will adopt a multidisciplinary approach, combining geological, geophysical, drilling information, and reservoir engineering data, along with advanced karstic reservoir modeling techniques to address key uncertainties and challenge karstic characterization, especially the uncertainty related to storage volume and containment. Finally, this would help us to improve karstic carbonate reservoir characterization & modeling for C02 storage and hydrocarbon production assessment.
Microfluidics – A New Tool to Differentiate Chemistry for Fracs – Functional Frac Performance Vs Reservoir Performance
Authors: Price B. , Li Y. , Liu S. , Abedini A.
Published: November 2024

Unconventional reservoirs play an important role in the global energy supply nowadays due to recent advancements in hydraulic fracturing. It has been reported that the selection of completion chemicals have a significant impact on oil and gas production due to fluid incompatibility and polymer-induced formation damage. To optimize oil and gas production, flowback efficiency, and fracturing fluid-induced permeability damage, different completion fluid packages were evaluated using microfluidics.

Two microfluidics chips were designed to evaluate regain conductivity and flowback efficiency in this work. The regain conductivity chips, representing proppant-packed fractured zones, were designed with two different fracture depths. The flowback chips consist of a high permeability zone and nanoscale channels to simulate fluid characteristics and transport in fractures, matrix, and their interface. Time-lapse microscopic images and videos of the chips were recorded during testing and the oil production was quantified using an automated images analysis platform. Microfluidic experiments were conducted using filtered produced water and oil samples collected from the field.

In microfluidics experiments, friction reducers with similar flow loop performance, or functional frac performance were chosen and compared on the regain conductivity and flowback tests. The results of the regain conductivity tests showed that the regain conductivity of the best performing group was 25% higher than the worst performing group. The flowback tests demonstrated significantly higher oil production rates and total oil flowback volume, about 50%, in the best performing group compared to the worst one.

This study introduces novel selection criteria for the design of completion fluid packages, aiming to optimize oil production in unconventional reservoirs. The pore-scale optical access of microfluidics enables a better understanding of formation damage and oil recovery mechanisms. Additionally, this microfluidic approach offers significant reductions in testing cost and time while providing improved reproducibility compared to traditional testing methods.
Enhancing Real-Time Stuck Pipe Prediction Using Trigger Coefficients: A New Approach for Realtime Well Engineering
Authors: Samuel Robello , Zhang Yuan , Agrawal Abhishek , Nakhle Amol
Published: November 2024

Conventional approaches to addressing stuck pipe scenarios in oil field operations have typically depended on established tools and procedures. While previous research has delved into the causes of drill pipe sticking and suggested adjustments in operational methodologies, current methods often fall short in predicting incidents comprehensively, particularly in light of diverse wellbore conditions. This paper presents a novel methodology that merges principles of physics, data science, and uncertainty modeling to offer more resilient and precise solutions for managing real-time pipe sticking occurrences. The methodology put forward embraces diverse modes of pipe sticking mechanisms, encompassing mechanical, geometrical, differential, keyseat, cuttings packoff, and geomechanical factors. Individual coefficients are assigned to monitor various parameters, with their weights dynamically tuned in real-time according to operational conditions and surface/downhole measurements. The independence of these parameters facilitates the prediction of mechanisms that contribute to pipe sticking occurrences. By integrating engineering and data science models through microservices, multiple calls during calculations are enabled, accommodating the expected nonlinear behavior of variables across various drilling conditions.

In real-time analysis, the findings indicate a fast convergence towards optimal prediction, ensuring predictability and favorable outcomes, particularly in test wells with inherent uncertainties. Interestingly, the study sheds light on the multifaceted factors contributing to pipe sticking conditions, even when initially perceived as differential sticking. Notably, in wells with minor doglegs, secondary geometric factors such as borehole torsion emerge as significant contributors to sticking. This leads to increased resistance against pipe movement in both axial and radial directions, elucidating the role of mechanical factors outlined by the well profile energy coefficient.

Moreover, trend analysis reveals a rising trend in pipe sticking conditions, attributed to uncertainties in input data. Furthermore, the integration of high-resolution lithology inputs enhances the accuracy of stuck pipe predictions. The prescriptive analytics approach comprises two modules: an inferencer and a recommender, providing operational parameters for intervention. The inference output offers practical recommendations to mitigate specific stuck pipe conditions. Additionally, in certain wells, the pack-off model and risk calculations incorporate insights from three primary models: cuttings bed buildup, caving volume concentration, and heightened friction on the drill string.
Advanced Embedded Discrete Fracture Network Modeling in a Complex Carbonate Reservoir: A Case Study from Abu Dhabi
Authors: Singh M. K. , Zhang L. , Rat C. , Al-Jenaibi F. , Al Kobaisi M. , Tahir S. , Kada Kloucha C. , Al-Kindi Z. S. , Mustapha H.
Published: November 2024

Fractured reservoirs present distinct challenges in the oil and gas industry due to their intricate origin and the dynamics of fluid flow within them. Successfully modeling these reservoirs entails surmounting multiple obstacles, such as delineating complex fracture networks, comprehending dual-porosity flow, and addressing scale dependencies. In this study we detail the application and assessment of innovative simulation algorithms tailored for fractured reservoirs within a complex, tight, and fractured carbonate reservoir located in Abu Dhabi, United Arab Emirates.

The reservoir, with more than 15 years of production history and 17 wells, has production from both matrix and fractured zones. Leveraging image log and other fracture drivers, a discrete fracture network (DFN) model has been constructed, considering the tectonic history of the basin. The reservoir was simulated using the embedded discrete fracture modeling (EDFM) approach. In this method, fractures are represented as discrete entities, each modeled with specific geometry, orientation, and properties, embedded within a porous matrix characterized by distinct properties.

By honoring the fracture geometry and fluid flow behaviors, EDFM modeling has become a versatile tool for simulating fractured reservoirs. It optimizes production strategies, identifies sweet spots, and improves hydraulic fracturing designs, ultimately enhancing recovery rates and economic viability.
Modelling of Propped Fracture Length for Variable Perforation Shot Designs in Unconventional Wells Undergoing Multi-Stage Hydraulic Fracturing
Authors: Alowaid Abdulrahman M.
Published: November 2024

The scope of this paper is to model the fracture geometry generated from different perforation shot designs in an unconventional well stimulated with multi-stage hydraulic fracturing. The objective of the paper was to assess the uniformity and symmetry of propped fracture half-lengths conducted through a sensitivity study on the number and distribution of perforating shot designs across a single hydraulic fracturing stage. A 3D transverse fracture simulation model was built using the petrophysical and geo-mechanical properties of an unconventional well, utilizing a commercial fracture simulation software. The objective was to identify the most optimum perforation design yielding the highest stimulation efficiency and fracture uniformity. Five different scenarios were tested: three scenarios with a uniform distribution of perforation holes per stage, and two scenarios with variable perforation distributions. The variable scenarios modeled higher distribution at the toe and heel sides of the stage for two scenarios, and consistent distribution with different number of perforations for three other scenarios. To guarantee a fair comparison between all scenarios, each was simulated with five clusters per stage. All five scenarios exhibited different distribution of fracture half lengths as expected. For the three scenarios with a uniform distribution of perforations per cluster, the lower the number of perforated holes per cluster, the more uniform the propped fracture half lengths were, indicating a clear correlation between fractures uniformity and the number of perforation holes. In contrast, for the two scenarios with variable perforation hole distributions, the one with higher perforation holes closer to the toe of the stage yielded a more uniform fracture geometry compared to the other scenario where perforation holes were concentrated more at the heel of the stage. The scenario with the lowest number of holes distributed uniformly yielded the most uniform distribution of fracture geometry out of the five scenarios. Consequently, the approach and outcomes of this paper are aimed towards the selection of optimum perforation designs, that yield similar fracture geometry symmetry, and ultimately have a positive impact on well deliverability.