bluuebunny/crossref_metadata_2025_split huggingface dataset:
Effective Utilization of Innovative Sand Screen Technology for Resolving Water Injection Challenges: A Case Study of Field X in Nigeria
Authors: Ngerebara Justus , Alawode Olusiji , Moradi Mojtaba 
Published: October 2023

Abstract
Numerous technologies have been deployed to improve the structural integrity and long-term efficacy of injection wells, ultimately enhancing oil recovery within a designated Nigerian field.
Thorough data analysis has indicated that the presence of formation solids arising from occurrences such as water hammer, backflow, and crossflow represents a substantial challenge to the integrity of multiple injection wells in the targeted field. This challenge is particularly pronounced when fines migration and accumulation within the lower completion take place during abrupt or extended well shut-ins. Although these formation solids generally reside within the reservoir during steady injection, they can be mobilized into the wellbore during rapid shut-ins due to the powerful transient flow effects of water hammer, cross flow, and backflow. This can lead to elevated bottom hole injection pressure (BHIP), reduced or lost injectivity, screen blockages, and erosion of downhole equipment. In turn, this may compromise the ability to sustain pressure support for producer pairs, potentially necessitating interventions, remediation, sidetracking, or wellbore abandonment. Alternative technologies previously applied in these wells have proven ineffective for a variety of reasons.
In light of these challenges, the novel NRV screen technology specifically developed for such projects was identified as the optimal solution from a range of available alternatives, based on a matrix of requirements for the new campaign. This technology, designed to be installed closest point to the sandface, was selected for its capacity to autonomously and immediately isolate the reservoir from the wellbore during shut-ins, its non-obstructive nature for intervention tools, its unhindered access to the lower completion sandface during injection and intervention, its durability throughout the well's operational life, compatibility with openhole standalone screen (OH-SAS), gravel pack (GP) completions, and direct wrap or metal mesh screens, as well as its cost-effectiveness compared to other options.
The performance data from the wells demonstrated that this innovative completion technology has effectively achieved the targeted rate and desired performance thus far, providing the Field X team with a robust solution to mitigate prevalent challenges in injection wells while avoiding the need for costly interventions.
Presently, the technology has been successfully implemented in three wells. This paper presents the pre-qualification studies, the comprehensive qualification test outcomes, and the subsequent post-installation performance of the wells. Also, the lessons learnt from these installations are shared.
Sustainable Economic Strategies for Corporate CEOs: AI-Driven Leadership in Driving Innovation, Growth, Safety, Sustainability, and Climate Change Resilience to Save Lives and Our Planet -A Comprehensive Comparative Policy Analysis on Unlocking Pakistan's Geothermal Potential
Authors: Aun Ali Syed Muhammad , Zaidi Syeda Fardees , Louis Clifford , Anjum Muntaha , Ali Syed Imran , Haneef Javed , Lalji Shaine Muhammadali , Ahmed Shabeer 
Published: October 2023

Abstract
This research investigates pressing need for sustainable practices, and examines the current state of geothermal energy development in Pakistan, despite its significant untapped potential. Through comparative analysis of policies and regulations prevalent in geothermal-rich nations like Iceland, the United States, and Kenya, valuable insights emerge. These insights can provide a roadmap for promoting geothermal energy growth within Pakistan.
Furthermore, the paper discusses about sustainable economic strategies tailored for corporate CEOs, centered around AI-driven leadership. It also illuminates the potential of artificial intelligence in steering innovation, promoting growth, enhancing safety measures, ensuring sustainability, and fortifying climate change resilience. By harnessing AI's capabilities, corporate leaders can play a pivotal role in safeguarding lives and the planet.
In addition the research addresses upon utilizing a comparative policy analysis methodology. The study evaluates institutional frameworks and arrangements of leading geothermal nations. By identifying challenges and opportunities specific to geothermal energy advancement in Pakistan, the research suggests strategic steps for progress. These include the formulation of regulatory frameworks, provision of investor incentives, and support for research and development. The study's outcomes contribute to energy security and sustainability, while its innovative perspective serves as a benchmark for Pakistan's geothermal initiatives. Moreover, these findings extend to other countries aspiring to harness their own geothermal resources.
Integrated Approach for Effective Asphaltene Precipitation and Deposition Detection in Greenfield Wells
Authors: Lee W. , Hamza M. , Shim J. , Mogensen K. , Grutters M. 
Published: October 2023

Abstract
This paper presents a comprehensive approach for assessing asphaltene precipitation and deposition in greenfield wells, which includes asphaltene risk evaluation using stock tank oil and bottomhole oil with and without miscible gas injection, the development of an asphaltene deposition simulation model employing PROSPER, and the interpretation of well operation results.
A holistic solution for assessing asphaltene deposition in greenfields is proposed by combining laboratory analysis, simulation models, and field data. The methods involve screening techniques using dead oil, such as SARA plot, De Boer plot, CII index. These preliminary results were complemented with AOP tests using live oil and field intervention outcomes to confirm the risk. A throttle model was developed to estimate asphaltene deposition in wellhead throttle valves, validated using wellhead choke inspection and well test data.
The comprehensive approach to managing asphaltene deposition in greenfield proved effective, as demonstrated by the results. The asphaltene risk assessment, well intervention activity interpretation, and simulation model successfully identified high asphaltene risk wells and targeted asphaltene treatment locations. Various screening methods determined different levels of asphaltene risk, with one method selected after comparison with AOP and field observations as the screening technique for new wells and reservoirs. Based on screening, asphaltene envelopes, and the deposition model, eight wells were chosen for asphaltene treatment.
This paper offers unique insights by introducing a comprehensive approach for detecting asphaltene deposition in greenfield wells. The novel wellhead choke model, in particular, enables a simple prediction of asphaltene deposition using existing wellhead parameters and well test data. The findings have significant implications for greenfield management and can be applied to other oil-producing regions globally.
Improved Up-Down Deconvolution in Ultra-Shallow Waters Offshore Abu Dhabi
Authors: Mahgoub M. , Cambois G. , Domont S. , Nassar T. 
Published: October 2023

Abstract
The ultra-shallow water-depth and hard water bottom of offshore Abu Dhabi are responsible for generating a complex multiple wavefield. Removing this energy is critical for accurate imaging of the subsurface. Almheiri et al. (2022), demonstrated the effectiveness of up/down deconvolution to attenuate multiple energy on Ocean bottom sensor (OBS) data from offshore Abu Dhabi. In this paper we detail recent advances to this workflow, leading to enhanced imaging results from offshore Abu Dhabi.
Amundsen (2001) showed that deconvolving the up-going wavefield by the down-going wavefield produces an estimation of the Earth's reflectivity series. While this technique gives a step-change in demultiple results from OBS data offshore Abu Dhabi, it suffers from high noise levels – particularly in the higher frequencies. Advances in linear noise removal enable the attenuation of mud-roll from the input data without harming the water-wave – an essential ingredient to up/down deconvolution. Removal of the mud-roll consequently enables better attenuation of shear-wave noise from the vertical geophone component.
The advanced workflow leads to improved wavefield separation and superior data for up/down deconvolution.The advanced pre-processing flow was applied to an OBS dataset from Offshore Abu Dhabi and used as input to up/down wavefield deconvolution. The up/down deconvolution results were benchmarked against a previous result from the same OBS dataset, without the application of the improved pre-conditioning flow. Reverse time migration (RTM) imaging using both datasets showed a clear improvement in signal-to-noise ratio on the new results, with improved reflector focusing, especially at the reservoir target level. Frequency band splitting showed better phase alignment across the bandwidth in the new data compared to the legacy results.
These results confirm that advanced de-noising techniques, allowing for the removal of high-amplitude mud-roll and shear-wave noise, without harming the water-wave, refraction energy or primary reflections, leads to improved wavefield separation and consequently improved up/down deconvolution results. The improved results exhibit reduced noise content, better event focusing and improved phase alignment across the frequency spectrum.
PSM Evergreening with Artificial Intelligence
Authors: Casal A. 
Published: October 2023

Abstract
Several "ad-hoc" safety assessments are routinely performed in Major Hazard Facilities such as Operational Risk Assessments (ORA), Management of Change (MOC) HAZOPs, Pre Startup Safety Reviews (PSSR), maintainability reviews and Root Cause Analyses (RCA). Recurrent safety assessments include HAZOP revalidations (re-HAZOPs), Safety Case / Safety Reports, BowTie reviews, etc. Undertaking these assessment in a coherent and systematic manner is problematic, not to mention keeping all the safety related information updated and in the same place.
This paper describes how Artificial Intelligence (AI) can be used to build and maintain a "live" functional twin of any industrial facility where Process Safety (PS) information is continuously updated and accessible to support standard risk management processes, which is the basic feature underpinning the concept of "Process Safety Management (PSM) evergreening". Employing Multilevel Flow Modelling (MFM), a functional twin of the facility is created by the HAZOP Assistant software application. With its reasoning capability, the model creates a map of all possible causal-effect relationships, linking causes with end consequences and safeguards alike a HAZOP study or a bowtie. This "live" map of causal-effect relationships can be accessed and displayed at any time in the form of an event tree or bowtie. The functional twin is not a database of words but an actual physical model which includes qualitative mass and energy balances. As PS knowledge improves, the model can be easily updated with the new information. When changes are made to the facility, the model can be updated to reflect the "as-is" status, so that safety assessments are updated and relevant.
The paper highlights how the HAZOP Assistant software application builds and maintains a functional twin of the facility to support the above processes consistently and efficiently, in one platform and reducing errors and costs.
Enhancing Structural Imaging and Well Data Integration with OBN 4C Data: Addressing Geological Uncertainties in Complex Deep Reservoirs
Authors: Ramli A. H. , Munif H. A. Ahmad , Zulkifli N. F. M , Bakar H. H. Abu 
Published: October 2023

Abstract
Objectives/Scope: The primary aim of this study is to illustrate the substantial advantages of utilizing Offshore Bottom Nodes (OBN) with four components (4C) for enhancing seismic image quality, thereby offering improved input for both static and dynamic models. Furthermore, the findings have proven instrumental in resolving long-standing discrepancies regarding fluid contacts in Field A.
Methods, Procedures, Process: The approach employed in this study involved a combination of well-established acquisition parameters and the implementation of a novel imaging algorithm, primarily the Full Waveform Inversion (FWI). By optimizing the acquisition setup, we achieved enhanced imaging of deeper zones, effectively reducing structural uncertainty and providing greater clarity on the structural shapes within these areas. Additionally, this approach facilitated improved continuity of amplitude in the presence of shallow gas. Fluid contact analysis at the well level was conducted by integrating log data, mud logs, pressure points, and production history for each well. Structural comparisons were also performed to highlight the notable differences in image quality when compared to traditional APSTM seismic images.
Results, Observations, Conclusions: The findings of this study demonstrate that fluid contact values, as determined through well logs, now align with the updated structural understanding of faulting and compartmentalization. This has led to enhanced structural interpretation, featuring more distinct fault imaging and partial resolution of shallow gas issues. The presence of shallow gas in previous seismic data resulted in the appearance of structural anomalies, causing images to depict sags as faults. With the new seismic images, multiple sand body pinch-outs were more readily identifiable, and boundaries were captured with greater clarity due to the higher resolution. Additionally, the generated Root Mean Square Attribute (RMS) significantly contributed to determining Field A's geological body, enabling accurate facies distribution across the field.
Novel/Additive Information: This study's innovative approach has yielded valuable insights, primarily stemming from differences in seismic acquisition techniques. The previous dataset employed a streamer method, whereas the latest dataset utilized an OBN (Ocean Bottom Node) approach. The new dataset features a more advanced seismic imaging technique, leveraging full-waveform inversion. The key lesson learned is the importance of continually updating interpretations based on the most current datasets, whether they are obtained through reprocessing or re-acquisition of data.
Novel Method to Calculate Free-Gas-Filled Porosity for Shale-Gas Reservoir and Production Prediction Using Wireline Nuclear Magnetic Resonance: A Case Study in Sichuan Basin, China
Authors: Rui Yun , Wang Yue , Niu Wei , Zhao Xian Ran , He Ye , Li Hui Geng , Shi Yang Zhi , Wu Jin Long , Pan Feng , Li Kai Xuan , Xu Lei 
Published: October 2023

Abstract
The performance of shale-gas wells varies significantly from well to well, and free-gas volume dominates the initial testing production of shale-gas wells. The uncertainties in pore-pressure estimation will lower the accuracy in quantifying the free-gas-filled porosity of shale-gas reservoirs, which translates into high uncertainties for the overall formation evaluation. Therefore, it is necessary to incorporate other methods independent of pore pressure for the free-gas calculation.
In this paper, the authors present a customized shale-gas formation evaluation workflow that integrates core analyses and wireline logging data. The pore fluid of the shale-gas reservoir is a mixture of free gas, adsorbed gas, and water. The hydrogen index and density of the free gas are different from those of adsorbed gas and water. The free gas, adsorbed gas, and water-filled porosities can be quantified when nuclear magnetic resonance (NMR) and triple-combo logs are incorporated, using an iterative method. A robust methodology integrating free-gas ratio (FGR) and other wireline measurements shows great advantage in shale-gas production prediction.
Case studies are presented from the shale-gas reservoirs of Taiyang and Daan Blocks in PetroChina's Zhejiang Oilfield. These case studies incorporate wireline-induced gamma ray spectroscopy, NMR, borehole images, dipole sonic measurements, and some special core measurements. The core NMR experiment and ion-milled backscatter scanning electron microscope indicate that the organic pore size ranges from 3 to 42.3 nm, the inorganic pore size ranges from 16.8 to 42.3 nm, and the ratio of organic pores to inorganic pores is about 2.5:1. The quantification of free gas, adsorbed gas, and water-filled porosities proves to be successful. The FGR varies in different wells. It is usually higher than 50% in the reservoir, and it can reach more than 80% in the sweet zone. Wells with high FGR prove to have promising gas production. Wells with abundant fractures and high formation dip angle prove to have low gas production. The core-validated petrophysical properties of lithology, porosity, permeability, total organic carbon content, gas content, water saturation, and triaxial stress magnitudes alleviate the uncertainties in determining the best zones.
In this paper, a novel application of core-validated formation evaluation of shale-gas reservoirs is discussed, which helps the operator ascertain the potential for future development. The FGR shows a good match to the gas production. The workflow can be applied to other shale-gas plays in China.
Novel NFDM Workflow: An Approach to NMR Data Processing for Accurate Fluid Typing and Saturation Determination
Authors: Gao J. , Kwak H. T. , Boudjatit M. , Althaus S. , Chen J. , Sørland G. H. 
Published: October 2023

Abstract
Accurate fluid typing and quantitative saturation determination are essential to evaluate reservoir production potential, which is a well-known deliverable by NMR measurements. However, challenges remain in obtaining these critical reservoir properties due to the ill-posed nature of Inverse Laplace Transform (ILT)-based NMR data processing and partitioning of overlapping continuous T1/T2 or 2D T1T2 distributions. This work presents a straightforward and efficient data processing workflow, the NMR fluid discretization method (NFDM), based on a new discrete inversion method, Anahess.
The first step in existing NMR data processing and interpretation is to apply the ILT methods with known issues of spurious peaks and broadening at the short relaxation time region. The overlapping peaks in 1D and 2D continuous distributions reflect the continuous oil and rock pore size distributions affected by the regularization factor. The second step of partitioning these overlapping peaks for fluid types is usually performed using manual cut-off, Gaussian decomposition, or machine learning methods, with considerable uncertainty and inconsistency. The new inversion method, Anahess, generates a limited number of unique discrete components that directly correspond to fluid types from the raw relaxation data.
The new NFDM workflow, a commonly-used ILT and an improved ILT method are applied to T1T2 measurements on synthetic samples, bulk fluid mixture (oil and water), and shale samples from multiple wells. For the synthetic samples of discrete components, the new method returned the components of accurate amplitudes and T1T2 relaxation times, while the ILT methods only gave approximate results through manual partitioning. The NFDM results from mixed bulk fluids also agreed very well with those from separate measurements. The true potential of the new workflow was illustrated in the analysis of shale samples, where different fluid types such as free oil, free water, absorbed oil, and clay-bound water, were easily determined and quantified by direct assigning the discrete components based on their T1 and T2 values according to a general fluid type NMR scheme. The production of different wells is expected to correlate positively with the free oil saturation. In summary, fluid typing and saturation determination were achieved using the new NFDM workflow with the Anahess inversion method, which eliminates the uncertainty, ambiguity, and inconsistency of existing ILT-based two-step approaches. Further applications to well logging and other NMR measurements using discrete inversion methods, including Anahess, are worth investigating.
Impact of Waxphaltenes on Overall Stability of Asphaltenes, Paraffins, and Emulsion
Authors: Punase Abhishek , Smith Rashod , Burnett Will , Mutch Kevin 
Published: October 2023

Abstract
Recent studies revealed that field deposits collected from production tubing of offshore wells often exhibit compositional variation pointing to more complex fouling process than original predictions based purely on asphaltene or paraffin instability. This deposit mixture generally comprises of 50-60% asphaltenes, 30-35% paraffin and remaining highly polar organics. The objective of this work is to understand the impact of Waxphaltenes co-precipitation on the overall performance efficiency of asphaltene inhibitors, paraffin Inhibitors, and Demulsifiers.
Routine screenings and initial chemical treatments were found unsuccessful for both asphaltene and paraffin application. Firstly, the oil sample was fully characterized though Fourier Transform InfraRed (FTIR) spectroscopy and High Temperature Gas Chromatography (HTGC). A series of dispersion and deposition tests were then conducted in order to identify potential chemistries for treatment. For asphaltene application, dispersion testing was mainly carried out using Asphaltene Differential Aggregation Probe Test (ADAPT) technique, whereas deposition tests were conducted on a customized Asphaltene Dynamic Deposition Loop (ADDL) test.
Crude oil characterization indicated presence of unstable asphaltene fraction within the analyzed crude oil sample. Dispersion efficiency with different asphaltene inhibitors revealed possible co-precipitation issue of other crude oil solubility fractions. Further characterization analyses highlighted heavier paraffinic components to have very high affinity towards the asphaltene clusters and creating waxphaltene precipitation issue. Efficiency of traditional asphaltene inhibitor chemistries were observed to not perform well for waxphaltene deposition. Similarly, paraffin application was tested using optical transmittance method and cold finger deposition setup. Moreover, rheological studies also highlighted issue of highly stable emulsion formation leading to complex fluid flow challenge. Improvement in the chemical treatment program and product development based on the knowledge obtained through this holistic work resulted in superior performing formulations. The deposition test results using the improved inhibitor chemistry was tested on ADDL and showed better performance than the traditional asphaltene inhibitor. Cold finger results also yielded softer deposit with overall lower mass on the fingers. Furthermore, considerable reduction in the emulsion stability was as obtained with addition of the combinatorial product.
The new approach presents a unique opportunity to revisit the way we do product development allowing chemical treatment strategy to be adopted and aligned based on actual deposit characteristics. Findings from this work allows more objective and reliable strategy to be adopted for offshore production with flow assurance management challenges caused by waxphaltenes deposition.