bluuebunny/crossref_metadata_2025_split huggingface dataset:
Novel Polymer Free Relative Permeability Modifier for Maintaining a Sustainable Water-Oil Ratio in Carbonate and Sandstone Formations.
Authors: Garcia Marieliz , Fragachan Francisco E. , Omer Mohammed 
Published: November 2024

Abstract
Water management strategies are applied to reduce water production from a reservoir, and often an increase in oil recovery is associated because of the wettability changes generated in the near wellbore area. The success rates of legacy water management strategies are low mainly because control of the water inflow is addressed at later stages when treatment effectiveness is less effective and the diagnostic for the source of water production is more difficult. Early reservoir management strategies are needed to effectively reduce unwanted water production.
This paper presents an integrated approach to characterize the problem properly, by incorporating an initial diagnosis from an intelligent monitoring tool that helps defines the nature of the problem followed by the injection of a novel relative permeability modifier – polymer free- characterized by a nano-particle system. The methodology involves the understanding of the reservoir current PVT (pressure, volume, temperature), performing a SARA (saturates, asphaltenes, aromatics, resins) analysis of the crude to define the colloidal instability index (CII). This CII, defined as the ratio of the SA to the RA, allows to determine where the precipitation of asphaltenes coating occurs; with a value below 0.7 defined as stable and a value higher than 0.9 as unstable. In oil reservoirs, when pressure falls below bubble point pressure the oil begins to release organics into the reservoir like asphaltenes. These asphaltenes begin to coat on the rock and negatively impact the porosity. The rock becomes oil wet.
The novel fluid system used is a colloidal suspension consisting of stabilized chemicals within a liquid phase. Due to their properties, they defy gravity forces and remain suspended within the carrier fluid in a random moving pattern. Shape, size, material, and concentration determine the effect of the fluid on specific application. The characteristics of such fluid systems were investigated through a series of core flood experiments to determine the effect of the fluid on the residual oil/residual water saturation and evaluate the water to oil ration (WOR) to determine the relative permeabilities.
This is a novel non-damaging technology which is independent of temperature and has been proven in more than 200+ wells in Latin America. The results demonstrated significant decrease on the water production and the WOR with enhancement in hydrocarbon production and proving zero damage on the oil producing zone. The solution proposed consists of the implementation of a recently developed analytical tool capable of integrating reservoir, completion, production, injection, and interventions history data, to diagnose the nature of the water production problem based on data analytics in conjunction with the novel technology to reduce the WOR.
Open Hole Gravel Pack Completion Through 7-5/8" Milled Casing Window for a High-Rate Gas Well, Offshore Trinidad
Authors: Douglas Dalton , Lutchman Deon , Ramnanan Avinash , Surajbally Rodney 
Published: November 2024

Abstract
The Angelin field lies off the Southeast coast of Trinidad. Development of the field commenced in 2018. The end of the useful life in certain wells created a chance to economically tap into the smaller reservoirs within the Angelin Field. This was achieved by repurposing and refurbishing the wellbores from the depleted wells. This process entails removing existing completion equipment (Decompletion), abandoning the previously exploited zone, and then drilling towards a new reservoir.
Sidetracking operations are performed to target the new zone. This is typically achieved by either cutting/retrieval of production casing or sidetracking of the current installed production casing. The decision is a factor of target location, production casing size and cement placement across casing sizes. Once the wells are drilled to TD, a new completion is installed.
The completion design is known as Slim Open Hole Gravel Pack completions, so-called ‘slim’ due to the reduced size of the lower completion section, which is required to pass through the smaller ID production casing.
Gravel packing has been employed in the Angelin field as the method of choice to manage sand production from unconsolidated and fragile subsurface formations in a high-rate gas environment. A distinctive characteristic of open-hole gravel pack (OHGP) compared to other sand control methods is its specialized screens. These screens contain ancillary shunt and transport tubes welded onto its core structure designed to achieving reliable sand control within the wellbore by providing alternative pathways for the gravel should there be any flow obstructions in the open hole. Although these features increase the reliability of the gravel pack job, they also introduce new potential failure points during installation to an already sensitive component of the well completion setup. Figure. 1Angelin Field offshore the island of Trinidad
Other critical components of the Angelin design include a fluid isolation device, gravel pack packer, gauge assembly and safety valve. Figure. 2Angelin Completion DesignFigure. 3Angelin Drilling Design
During the recompletion of one of the Angelin wells, the well was unable to be delivered as designed during well execution due to stuck pipe (production liner) above the reservoir interval which eliminated the initial plan of accessing the reservoir with the base case design. The option available for progressing the well was to access a shallower target across the stuck pipe via section milling or whipstock. The paper discusses the deployment considerations for both options and the eventual execution strategy used to successfully circumvent the high risks of deploying a slim-hole completion through a milled window.
Successful Underbalanced Well Completion Operations in Depleted Carbonate Reservoir of Brown Gas Field a Case Study
Authors: Haris Qureshi. , Sahir Inam. , Zulfiqar Anjum. , Sana-Ul-Hussnain Syed. , Ibtihaj Atiq. , Mudassir Khan. , Uzair Qadir. 
Published: November 2024

Abstract
One of the main goals for oil and gas operators is to optimize reservoir productivity and enhance the ultimate recovery from depleting fields. Underbalanced drilling stands out as a pivotal technology embraced globally to accomplish various objectives aimed at maximizing reservoir potential. Among these goals, the primary aims are to minimize formation damage, pinpoint favorable zones within the reservoir, and trim down overall well expenses. Drilling the reservoir section underbalanced but completing the well overbalanced significantly affects the overall productivity of the reservoir. In addition to that, well control and killing operations during drilling and completion phases exacerbate the issue, leading to prolonged well delivery timelines and escalated costs. In response, this study delves into the successful case study of the groundbreaking underbalance slotted liner running followed by underbalance completion operation.
The primary objective of this case study was to complete the well in underbalanced mode from dry hole to completion by utilizing the state-of-the-art technology which helps in bolstering well productivity without damaging the reservoir integrity, contrasting with conventional overbalanced methods. Methodologically, underbalance completion operations relied on the utilization of rotating control devices and downhole deployment valves for precise control, offering advantages such as enhanced reservoir connectivity while posing a few challenges which are also discussed.
Results showcased notable improvements compared to offset wells. The underbalanced approach reduced cumulative drilling and completion days by 25%, resulting in a cost saving of 17%. Most significantly, the comparison of flowing rates revealed a substantial gain of 34%, highlighting the efficacy of underbalance strategies in optimizing performance. The successful implementation of underbalance operations proved instrumental in achieving desired production rates by avoiding the extensive well killing operations and costly acid stimulation treatments, thus underscoring its pivotal role in reservoir management and productivity enhancement. This paper discusses the planning, design, execution, and lessons learnt in underbalanced drilling and completion operations in the subject field.
Examining the Corrosion Behaviour of Carbon Steel Pipelines with Bio-Corrosion Inhibitors in Sub-Sea Environments
Authors: Ayan Mohd , Garg Aaditya , Sharma Rohit , Agarwal Shilpi , Deka Barasha 
Published: November 2024

Abstract
This paper embarks on an extensive investigation into the corrosion behavior of carbon steel pipelines across aqueous environments. It aims to evaluate the effectiveness of bio-corrosion inhibitors, specifically focusing on beetroot powder doped with NaNO2, in bolstering the durability of these pipelines. The study encompasses a multifaceted analysis, including quantification of corrosion rates, and assessment of the inhibitor's impact on pipelines in various sub-sea fluid conditions. The combination of beetroot with NaNO2 presents a promising avenue for corrosion inhibition, aligning with sustainability goals and offering a potential solution to enhance pipeline longevity.
The research methodology employs immersion experiments with carbon steel samples to scrutinize their response across seawater environments. Bio-corrosion inhibitors are rigorously tested in aqueous samples using a wet immersion technique, wherein a solution of beetroot powder doped with NaNO2 is prepared. Experiments are meticulously conducted utilizing a 4 wt./volume % NaCl solution, with the churned beetroot powder doped with NaNO2 at varying loadings, typically ranging between 18% to 64%. The resulting inhibitor doped samples were tested through FTIR analysis and microscopic analysis, in order to understand the changes in the corrosion environment, and finally the corrosion measurement calculations, corrosion rate calculations and inhibition efficiencies were calculated.
The experimental findings unveil a substantial reduction in corrosion rates, particularly notable in seawater conditions (NaCl solution), where the combination of beetroot powder and NaNO2 demonstrates superior effectiveness. Visual observations compliments the significant decrease in corrosion by 47.2 wt.% with the utilization of the bio-corrosion inhibitor blend. This innovative approach not only offers a practical and environmentally friendly strategy for corrosion prevention in pipelines but also underscores the potential of organic inhibitors in mitigating corrosion challenges.
This study contributes novel insights into the efficacy of bio-corrosion inhibitors, shedding light on the synergistic effects of beetroot powder with NaNO2 in combating corrosion in carbon steel pipelines. The presence of organic compounds in beetroot, coupled with the corrosion inhibition properties of NaNO2, enhances the protective capabilities against corrosion, thus showcasing the potential of natural substances in corrosion management. Understanding the performance of bio-corrosion inhibitors across diverse environmental conditions is pivotal in devising tailored strategies to optimize pipeline durability and ensure reliable operation in varying contexts.
Plunger Lift Working Cycle Optimization using a Dynamic Full-Cycle Model Coupled with Simultaneous Perturbation Stochastic Approximation (SPSA) Algorithm
Authors: Chen Mai , Zhu Jianjun , Cao Guangqiang , Li Nan , Wang Haoyu , Zhu Haiwen , Jia Min , Yang Xiaopeng , Guo Donghong 
Published: November 2024

Abstract
This paper presents a novel approach to optimizing plunger lift operations in gas wells through the development of an improved dynamic model and an efficient optimization algorithm. We introduce an enhanced plunger lift mechanism model that integrates reservoir dynamics using classic production relationships, such as Vogel's Inflow Performance Relationship (IPR), and accounts for variable plunger velocities. The model combines a two-phase component approach for liquid and gas with a black oil model, improving the accuracy of fluid property estimations and providing a versatile simulation tool. To address the limitations of traditional optimization methods, we implement an improved Simultaneous Perturbation Stochastic Approximation (SPSA) algorithm. This allows for real-time, intelligent optimization of critical plunger lift parameters, including cycle duration, plunger ascent time, and control valve status. The optimization method is applied to both dual-cycle and quad-cycle plunger lift scenarios. Results demonstrate significant improvements in net present value (NPV), with increases of 65% for dual-cycle and 98% for quad-cycle operations, without modifying underlying reservoir or fluid models. The model's key operational parameters show strong agreement with commercial software results, validating its accuracy and reliability. This research contributes to the advancement of plunger lift technology by providing a more accurate dynamic model and an efficient optimization methodology. The proposed framework offers valuable decision-making support for field operations, potentially leading to substantial improvements in production efficiency and economic outcomes in gas well operations.
Leading the Way: Surveillance Planning and Integrated Interpretation for the First Low Tension Gas (LTG) Flooding Pilot in North Oman's Carbonate Field
Authors: Das Anindya , Al-Amri N. , Al Abri M. S. , Mahruqi D. , Abuawad A. , Itua O. J. , Ghufaili A. , Abram P. , Groenenboom Jeroen , Kahrobaei S. , van Batenburg Diederik , Abdullah I. , Al Bimani S. A. 
Published: November 2024

Abstract
The LTG approach employs surfactants to reduce the interfacial tension between water and oil, facilitating the mobilization of residual oil alongside foam for effective conformance control. This pilot was initiated to gather data to address critical remaining uncertainties and threats militating against full maturation of the opportunity. This paper sheds some light on the outcomes and insights extracted from the surveillance log data that played a crucial role in affirming if the first Oman foam pilot for LTG flooding is a success. Surveillance logging data played a pivotal role in determining the distribution of injected fluids and quantifying fluids saturation over the trial period. Advanced pulsed neutron technology and injection logging data from two wells within the carbonate field were utilized for the evaluation.
The injection strategy for two wells comprised multiple cycles of immiscible Water-Alternating-Gas (WAG) injection using N2 to establish a baseline, succeeded by multiple cycles of Surfactant Alternating Gas (SAG) injection for foam generation. A comprehensive surveillance program was deployed for continuous monitoring of pressure responses, saturation profiles, injection conformance, and reservoir fluid dynamics, enabling a thorough assessment of the SAG flooding process. Injection Logging data was undertaken for conformance monitoring during the injection phase. Analysis of pressure and temperature data was performed before and after injections to identify any potential occurrences of crossflow during shut-in phases. Additionally, advanced pulsed neutron data was acquired to monitor changes in gas, oil, and water saturation over time following each injection stage.
Interpretation of petrophysical advanced pulsed neutron and injection logging data, aided in assessing saturations within the relevant formations both before and after injections. Additionally, the injection logging data provided insights into injection intervals, assisting in the evaluation of fluid injection, and facilitating the planning of subsequent injection phases. The integration of these findings enabled one of the key project objectives to establish if foams can be generated during this LTG pilot process to be addressed.
The pre job planning and real-time support for data acquisition, rush interpretation, and integration of findings enables the team to efficiently strategize operations at each injection. Successful integration of pulsed neutron data and PLT data with the help of advanced log interpretation helped to establish that foam was generated from Low-tension gas flooding process in the carbonate reservoir.
Multi-Scale Fracture Modeling and its Application: A Case Study of the Zhaotong Shale Gas Demonstration Area in Southern China
Authors: Liu Yang , Xian Chenggang , Huang Xiaoqing , Liu Yunyi , Liu Mingyang , Wang Jianjun 
Published: November 2024

Abstract
The study area has been influenced by multiple phases of tectonic movements, resulting in complex geological structures characterized by fractures of various phases interweaving and embedding. This complexity has led to suboptimal outcomes in shale gas fracturing development. To accurately describe the fracture systems in the study area, this paper employs a multi-scale fracture modeling approach based on the comprehensive application of multidisciplinary data, including geophysics, geology, logging, and geomechanics. We established a three-dimensional model of natural fractures at three scales: seismic Facies fractures, discrete fractures, and diffuse fractures. This model was validated using imaging logging, drilling data, and microseismic monitoring of hydraulic fracturing. The model can be effectively used for the integrated analysis of drilling mud loss, fracturing operations, and productivity testing, thereby enhancing the effectiveness of fracturing operations and supporting the efficient development of shale gas in the study area.
A New Slimhole LWD Imager for Hostile Downhole Environment: A Kuwait Story from Deep Jurassic Tight Carbonate Rock
Authors: Al-Azmi M. , Al Ajmi S. , Al-Ajmi H. , Al-Hashash M. , Joshi G. , Al-Otaibi F. , Al Saadi D. M. , Shadad N. , Alraish A. , Pasaribu I. , Chambers B. , Shrivastava C. , Lashin Y. 
Published: November 2024

Abstract
Tight carbonate reservoirs of north Kuwait present many challenges for field development due to the inherent low porosity and permeability characteristics. The reservoirs are characterized by an average matrix porosity from 2 to 6% and permeability from 0.01 to 1.5 md. Near critical gas and volatile oil fluids produce mainly from Middle Marrat carbonate multi flow unit reservoirs. Natural fractures play a primary role in the producibility of these reservoirs and understanding the fractures and rock texture are important to the characterization and subsequent stimulation strategies for production.
High deviated well is commonly used to intersect the potential natural fractures and connect the multi flow unit inside Middle-Marrat carbonate. Multiple pressure regime encounter from the upper part of Jurassic layer resulted in the required 6in slimhole to be used to drill the target Middle-Marrat formation. Drilling risks are aplenty in downhole conditions made hostile by high viscosity synthetic mud with high solid content for a 6-in deviated hole going through varying pressure profile amidst high torque and drag. These challenges and slimhole size often limit the technology availability on acquiring high quality measurement especially with a borehole imager for fracture characterization.
The new logging-while-drilling (LWD) tool presented in this paper overcomes these challenges while delivering services in 18 to 19 lbm/gal (ppg) of synthetic-oil-based-mud (SOBM). The tool features an extremely compact 5 ft long LWD sub, which includes a power source, memory and directional sensors for azimuth and high side offset detection. The compact size sub allows for placement near the bit and reduces overall required bottom-hole-assembly (BHA) length. The torque and drag of the logging run in the cleaning out assembly were studied to ensure smooth acquisition minimizing risk of stuck pipe.
An Integrated Machine Learning Algorithm for Unconventional Flowing Bottomhole Pressure Prediction During Dynamic Gas Lift Operation
Authors: Jin Miao , Emami-Meybodi Hamid 
Published: November 2024

Abstract
Machine learning algorithms have been used to predict flowing bottomhole pressure (FBHP), but past research often neglected data characterization, affecting accuracy. We developed an integrated ANN model by embedding and categorizing multiphase flow physics to improve FBHP predictions under varying conditions. We collected data from 16 deep shale oil wells in the Permian Basin, Texas. Inputs for the machine learning model were derived from multiphase flow physics analysis, including oil/gas/water gravities, injection depth, wellhead pressure and temperature, well temperature gradient, liquid flow rate, gas-liquid ratio, and water-oil ratio. The physics-based ANN model was created using a simulation dataset and field data, while the data-based ANN model was developed directly from the 16 wells. Both models predicted FBHP for four new wells over their entire period and one new well with early months’ data. We also explored the combination of an unsupervised clustering model with the physics- and data-based ANN model for FBHP prediction.
Integration Of Innovative Real-time Extra-Deep Mapping Technology Maximizes Reservoir Exposure And Increased Production Potential Of A Complex Reservoir - A Successful Case History From The Largest Onshore Field, Libya
Authors: Al-Ansari Yusuf , Mumtaz Asim , Potshangbam Sanathoi , Hameed Mahmoud , Alaogali Issa , Elwirfili Ibrahim , Elsteil Mohamed , Ezarrug Nabil , Alkelani Khaled , Al Shlib Abdelhakim , Ezwai Jamal , Almuntafeky Ali 
Published: November 2024

Abstract
Exploiting the full potential of a complex reservoir in Libya's largest oil field is inherently challenging due to variable reservoir characteristics such as thickness, heterogeneity, water height uncertainty, and sub-seismic faulting. These geological complexities can significantly hinder effective navigation and optimal placement within hydrocarbon-bearing zones, necessitating the utilization of advanced reservoir navigation tools. This paper highlights how advanced geosteering technology can overcome complex reservoir challenges, leading to better well placement and increased hydrocarbon production.
To achieve the well objective, it is critical to optimally land the well in the target zone, mitigating the challenges due to geological uncertainty. Drilling further in the lateral section requires maintaining the trajectory in the best reservoir properties while tracking the Oil Water Contact (OWC) below for any elevation changes. A feasibility study based on offset data respecting the area's geological setting was undertaken to determine the best fit-for-purpose technology. Extra Deep Azimuthal Resistivity (EDAR) technology was identified as the optimal solution to detect resistivity contrasts remote from the wellbore, thus avoiding penetration.
EDAR ultra-high-definition (UHD) real-time inversion analysis facilitated the precise mapping of multiple resistivity layers and accurate delineation of the Oil Water Contact. This ensured well-informed and proactive geosteering decisions to land the well and expose the reservoir optimally. The EDAR inversion continuously mapped the top of the target zone along with the local dip variations, interpreted sub-seismic faults, and defined their throw. This technology was essential for maintaining a precise and smooth trajectory in a geologically complex area, achieving 100% reservoir contact, and optimizing hydrocarbon recovery. The information acquired from the inversion summary, such as resistivity distribution and structural changes, is valuable input for enhancing the field development plan of the area.
The use of advanced geosteering tools improves navigation accuracy in complex reservoirs, setting a new benchmark for challenging environments.