bluuebunny/crossref_metadata_2025_split huggingface dataset:
Corrosion Inhibitor Characterization with Rewarding Laboratory Tests for Oil Pipelines
Authors: Hirano S. , Mizukami H. , Sei T. , Yasui A. , Sunaba T. 
Published: November 2024

Abstract
Oil-soluble and water-dispersible corrosion inhibitors are normally used to mitigate corrosion in pipelines operating. The performance of corrosion inhibitors has been described mainly in terms of the adsorption of surfactants on metal surfaces. The persistence of the adsorbed film is primarily evaluated by corrosion tests. That is why the corrosion tests are the main technique for the inhibitor evaluation. However, the partition of the surfactant from oil to water and its dispersion in water should also significantly affect the corrosion inhibition mechanism. We propose the evaluation methods and show examples of quality evaluation. The corrosion inhibitor was characterized with relatively familiar instruments at the oil company's laboratory. Those measurement such as average molecular weight, TOC, Zeta potential and particle size were conducted among the qualification of corrosion inhibitors. As a result, the amount of dispersion, the stability of dispersion and the some component could be evaluated even for commercial products in more detail. Those data must be useful to assess the quality stability and will contribute the inhibitor selection.
Mathematical Modelling of Co-Current and Counter-Current Spontaneous Imbibition into a 2D Matrix Block Accounting for Boundary Conditions, Gravity and Viscous Coupling
Authors: Qiao Y. , Andersen P. Ø. 
Published: November 2024

Abstract
Spontaneous imbibition is a mechanism where capillary forces drive multiphase fluid flow such that non-wetting fluid is displaced by wetting fluid. This is relevant in naturally fractured reservoirs where matrix blocks are disconnected by a highly conductive fracture network. Traditional modeling approaches tend to rely on Darcy's law with relative permeabilities. However, many experimental works have shown features such as reduced mobility or delayed onset of imbibition that are not captured by these standard approaches but can be explained by viscous coupling (which causes more flow resistance during counter-current than co-current flow). These terms arise naturally in the fundamental momentum equations describing fluid flow. In a dynamic setting where flow regimes may change locally and with time there may not be a simple way of upscaling observed laboratory data. In this work we therefore explore imbibition in a setting where water and oil cover a 2D matrix block with some or all surfaces open, including mechanisms of viscous coupling and different flow regimes due to various boundary conditions of the system. The input parameters are based on experimentally matched data where the non-standard terms are accurately and uniquely quantified. The code is validated against commercial software for cases where the non-standard terms are negligible. Imbibition rate increases when opening more area to water or oil. For a given open area, there is an optimal area fraction open to oil that minimizes the recovery time long term. At early time recovery primarily increases with the area open to water. Viscous coupling increases the imbibition time when more of the production is counter-current, i.e. a higher fraction is exposed to water. The generalized model with a specific term accounting for viscous coupling produces similar behavior as conventional modeling for cases dominated by co-current flow because of applying relative permeabilities measured under such conditions. Increasing water viscosity appeared to reduce imbibition rate more for co-current dominated cases than counter-current dominated cases. For cases with same open area and same areas exposed to water and oil, a more concentrated distribution of oil at the boundaries is unfavorable for oil recovery, compared to a more even distribution.
Seismic Reservoir Characterization Workflow with a Fast Post-Processing Update to Handle the Unfavorable Seismic Conditions of the Onshore Middle East Carbonates
Authors: Baturin Mikhail , Lombardi Morgane , Hamdi Mahmood Hamdi Hassan , Ahmed Jahan Zeb , Ben Maroof Muneera Saleh Salem , Pramudyo Yuni Budi 
Published: November 2024

This paper describes the joint acoustic-porosity seismic inversion study performed on the seismic data from a field in UAE anticipated by a seismic reservoir characterization feasibility study with an aim to control the quality of the input dataset and its fit for the declared aim as well as to define the most efficient seismic inversion method and updated with a quick amplitude correction to compensate for the unwanted seismic artefacts.
The main challenges were related to the seismic quality issues proceeding from the onshore sand dunes constrained acquisition environment and the bandwidth limitations due to the carbonate reservoir domain.
Quality control of the input seismic data revealed a necessity for the correction of the seismic amplitude suffering of surface-related effects in an efficient yet a timely manner due to the operational time constraints. The corresponding procedures were defined and applied. Yet such approach is potentially associated with the risks to the preservation of the true seismic amplitudes and thus required detailed quality controls to ensure a geologically meaningful output.
Cost Effective Remote Magnetic Inspection of Pipelines. Case Study
Authors: Ablaev Anton , Zozulya Andrey 
Published: November 2024

Abstract
This article presents a technology for Remote Magnetic Inspections (RMI) of pipelines based on the Villari effect. The technology consists of a measuring device, a magnetic field and a software package. The paper presents general description of technology, some procedure and recommendation for technology method, and it is advantages comparison to other methods. The results of the pilot jobs showed a correlation with conventional inspection of the pipeline after excavation at the few pits. Remote magnetic inspection is faster and cheaper than other conventional methods.
The company has developed a new remote magnetic inspection tool with GNSS sensor that allow to detect anomalies with better accuracy, also company develop new software that use artificial intelligence to process the data faster and with better results. Several pilot works were carried out, which showed the correlation of the data with direct measurements of pipeline after excavation of the pit.
Diagnostics proceed as follows. The operator walks along the pipe and measures the change of the magnetic field in places where there are defects in the pipeline, the magnetic field is distorted, and the defects and anomalies can be determined.
All data is registered at the software and processed using artificial intelligence. The customer receives a final report with a map of anomalies, each anomaly categorized by 3 categories (normal, critical and supercritical). After that client prioritize pipeline fixing activity.
This technology can be used where in-line inspection cannot be carried out; in addition, this technology is several times cheaper than in-pipe inspection, and it does not require preparation and shutdown of the pipeline. New equipment allows pipeline inspections to be carried out faster (up to 50 km per day when using drones), cheaper and without stopping pipelines.
Static and Dynamic Reservoir Rock Typing of Highly Heterogeneous Fluvial Delta Marine Sands Deposited in Mesopotamian Basin
Authors: Akbi H. , Aidarbayev S. , Qiu M. , Al-Wadi A. 
Published: November 2024

AbstractGeological reservoir study is a crucial step to understand the reservoir properties that drive hydrocarbon flow behavior as part of reservoir life cycle. Among them, sandstone reservoirs have a lot of challenges when the data is scarce to integrate and link between the different disciplines. Nevertheless, a collaboration between geologists and petrophysicists paved a way to systematically fill data gaps which resulted in understanding of petrophysical distributions and the degree of heterogeneity.The methodology starts with a principal component analysis of logs to identify useful data for prediction. It uses the core description, XRD and the thin section to reveal the major diagenetic events and critical mineralogy. Simultaneously, this workflow calculates the hydraulic flow units (HFU) based on core data (K, Phi) flow zone indicators, discrete rock types and global hydraulic elements. The stratigraphically modified Lorenz plot is used to identify storage capacity and flow capacity to detect high permeability flags. The static characteristics are linked with the dynamic HFUs to decipher cloud boundaries that have unique geological and fluid-flow parameters.The core description shows the following depo-zones within a fluvial delta marine sand: delta front mouth bar, distributary channels, distributary mouth bar and prodelta rock types. The thin section indicates the influence of kaolinite and cementation in some reservoir intervals. This knowledge was incorporated to calculate permeability with a higher precision (R2= 0.9 – 0.98) in comparison with core permeability. The FZI method showed seven rock types. Stratigraphically modified Lorenz plot used pore-throat radius, storage capacity, flow capacity, and reservoir speed characteristics. This technique resulted in 5 to 8 hydraulic flow units that divided the Poro-Perm cloud into barrier, baffle, normal flow, and super flow based on slope changes. The distributary channel has the best rock type, while the delta front mouth bar and distributary mouth bar have the medium to the worst rock types while the prodelta has the poorest rock types.Through the integration of sedimentological and petrophysical data, this workflow enables the characterization of highly heterogeneous sandstone reservoirs. Its result improves the prediction of rock type, permeability, and water saturation properties in geological models. Furthermore, it optimizes the number of RRTs to reduce uncertainty resulting in the creation of a robust static model and a better prediction during the implementation of the dynamic model.
Automated Production Allocation & Deferment Calculation Using Integrated Digital Oil Field Realtime Surveillance Data and Physics Based Well-Models
Authors: Al Jabri Kawthe , Al Hinai Ahme , More Anand Raosahe , Kumar Nitis , Kumar Suresh 
Published: November 2024

Abstract

Objectives/Scope
Automate Production Allocation and Deferment calculation workflow using Integrated Digital Oil Field (DOF) realtime surveillance data and physics based well models benefitting ARA Petroleum's Production Optimization team by improving Field Allocation factor, improving DOF system performance, reduce production losses caused due to delayed & errored manual calculations processes and integration of this data with Business Intelligence (BI) and cross domain applications. Achieve complete digital transformation of the process.

Methods, Procedures, Process
DOF team developed physics-based models for all wells (ESP, PCP and Naturally flowing types) using PVT, Completion, Artificial lift system data and integrated these models with DOF Real time data (RTD) for automatic estimation of Well rates. Using Well Management System (WMS) and Real time data of custody transfer meter, calculation of Field factors was automated to generate Allocated rates automatically. The process was coupled with daily well flowing hours to estimate deferment production due to well downtime, trips. This daily automatic workflow task is scheduled on Production server for faster and accurate data generation of daily and average allocated rates. This paper describes in detail the workflow used for implementation of the process.

Results, Observations, Conclusions
Since implementation of the Automatic Allocation and Deferment workflow, it has maintained daily and average allocated rates for 80+ ESP, PCP and Naturally flowing wells in the field. Application of the workflow has resulted in improved ability to track production with targets. Corrected Allocated rates w.r.t optimized well parameters is an added advantage of this workflow rather than using constant rates between two valid well-tests which was an outdated traditional approach. This allocated rates data has helped ARA petroleum engineers to accurately; compare production with target plan, optimize well/reservoir performance, perform material balance and/or reservoir history matching, run production forecasting, perform hydrocarbon accounting, estimate produced reserves, take reservoir management decisions, implement EOR, plan well intervention etc. Below are the key results by successful implementation of the workflow:
The input and output database of this workflow is successfully integrated with BI and other cross domain applications for quick and efficient analysis.

Novel/Additive Information
The utilization of real time surveillance data and Well models have proven to be an efficient way to maintain accurate well and/or field wise allocated production rates and deferment volumes automatically. Well and Region wise reports are easy to prepare with this digital data source, to track Production performance for ARA petroleum Assets.
Enhancing Offshore Operations: Secure Data Sharing for Automatic Oil Spill Detection
Authors: Røstad J. , Prytz G. 
Published: November 2024

Abstract
Early and reliable automatic Oil Spill Detection is vital. The earlier a spill is detected, the less chance it has of causing an environmental disaster. As the popularity of Oil Spill Detection has grown, information integrity and cybersecurity are becoming increasingly important for safe and unbiased reporting. Secure data sharing fosters trust and collaboration, facilitating transparent decision-making.
Automatic Oil Spill Detection is done by physics-based image processing from X-band radars streams. Verification and volume estimation can be achieved from added infrared cameras.
To make sure the detection is un-tampered, modern information security systems following ISO 27001 procedures are needed. By creating a secure end-to-end pathway, information can flow from the physical detection through the monitoring software and to the onshore stakeholders - in Oil Spill Detection context: the operator and environmental authority as the regulator. Only then all parties can be sure of having the same information at the same time.
Major oil operators and offshore vessels have for years used remote sensing instrumentation critical for their operation. Locked in data has been a major issue for operational excellence improving revenue and HSEQ. Adding the most modern technology within IoT, cloud and information security has made data easily available with improved offshore operations in multiple areas. A faster oil spill response is achieved since alarms earlier reach everyone involved in surveillance and recovery teams. Waiting on weather is greatly reduced by having access to the right data. Some operations have weather limits where accurate data removes doubt. Other operations experience problems that can be mitigated by enhancing the understanding of the sea state. Having multiple users of the same data also results in a reduced need for various measurement systems, reducing carbon footprint and conducting a more sustainable operation. It is also a critical tool in building trust to authorities through unbiased reporting and transparency.
Remote sensing techniques have proven their popularity. This paper demonstrates how modern information technology helps by adding more value to tested and proven sensors and systems within Offshore Marine Operations.
First Middle East Single-Trip Intelligent Completion Installation with Both an Electrical Submersible Pump (ESP) and a Downhole Wet-Mate.
Authors: AlRaml Haida , Ufondu Kene O , Al Haj Ahme , Almasri Abdulrakeeb 
Published: November 2024

Abstract
Intelligent completions in multizone wells require hydraulic control lines tied back to surface. To reduce capital expenditure (CAPEX) and complexity related to workovers to replace ESPs, a downhole wet mate was implemented in those intelligent completions.
This paper discusses further optimizations made to facilitate and simplify the deployment with only one trip. This improvement to achieve a single trip has significant positive impacts on health, safety, and environment (HSE), formation exposure, deployment complexity, and CAPEX.
The innovative single-trip intelligent completion system with ESP and downhole wet-mate eliminates the need for the ICVs and zonal feedthrough isolation packers to be run on drill pipe. All the completion components are installed in one single trip. The lower completion zonal feed-through isolation packers are set through the packer setting control line via a surface hydraulic pump, followed by setting the ESP packer by applying tubing pressure against a slickline plug.
The single-trip intelligent completion with ESP and downhole wet-mate was successfully deployed in the Middle East. This installation saved 27 hours of rig time.The complexity of the installation and HSE risks were eliminated by:Eliminating the requirement to pull the drill pipe with control lines and the large clamps.Isolating the formation during tubing hanger landingAll well objectives were met.Deployed all equipment successfully on a single trip.Confirmed the integrity of the packers.Successfully functioning of the ICVs.
This paper will discuss the novel aspects of implementing a single-trip intelligent completion with ESP and downhole wet-mate through the utilization of control-line set zonal feed-through isolation packers.
New Guideline for Corrosion Under Insulation
Authors: Wiggen F. , Jessen J. V. , Rivero A. R. , Aanesen R. 
Published: November 2024

Corrosion Under Insulation (CUI) is considered one of the major threats to integrity of process facilities. The Net Zero Technology Centre (UK) estimates that CUI now contribute to over 20% of the major oil and gas accidents reported within the EU since 1984 /1/ and regulators in the North Sea report that 50% of the reported hydrocarbon leaks is caused by CUI /2/. Earlier industry publications /3/ suggest that CUI accounts for more than 40% of a plant's piping maintenance expenditure and 10% of the total maintenance budget.
A Joint Industry Project (JIP) consisting of oil & gas operators in the North Sea and DNV resulted in 2019 in a new recommended practice, DNV-RP-G109 "Risk Based Management of Corrosion Under Insulation" ©/4/ where a new qualitative risk methodology was introduced to the industry. This methodology is based on assessment of 4 barriers, the material barrier, the coating barrier, the water wetting barrier and the design barrier/5/. The methodology is now referred to as a preferred methodology to manage CUI by legislators in Norway /6/ and are taken into use in several other countries as well.
This paper will address the forthcoming update of DNV-RP-G109 related to CUI in corrosion resistant alloys and the use of humidity sensors to assess probability of water wetting in the insulation.
3D Seismic Processing Involving UDD and SCDC Application in the Transition-Zone in Abu Dhabi, UAE
Authors: Hu Junhui , Ye Zaibing , Chen Yingpeng , Gao Junqi , Cambois Guillaume , Mahgoub Mohamed 
Published: November 2024

Abstract
Transition-zone (TZ) seismic surveying is difficult as it involves operating in land, marine and intertidal areas, which are often environmentally sensitive, and have a multitude of source and receiver technologies, each adapted to a particular terrain. This diversity in acquisition is also challenging for processing, for which the goal is to provide a seamless image of the subsurface regardless of the terrain and the technology used to record the data.
Our strategic approach unfolds in two pivotal phases: initially, it focused on comprehensive noise removal across land, intertidal, and marine. Meanwhile, meticulously addressing variations in amplitude RMS and wavelet characteristics associated with diverse terrains, sources (dynamite, vibrator, different Airgun with distinct signatures, and corresponding surface ghosts), and receivers (GPR nodes which used for recording marine data, GSR nodes which for land data).
Secondly, an Up/Down Deconvolution (UDD) was adapted to work within ultra-shallow water offshore environments. Where UDD was not applicable in onshore and intertidal areas, surface-consistent spiking deconvolution (SCDC) was applied instead, and with additional light matching process, the final connection between UDD and SCDC was seamless.
Denoise and multi-mode seismic data preconditioning work were challenging, it was also observed that offshore records were dominated by mud-roll and guided wave, while ground-roll and ambient noise prevailed onshore. The intertidal area suffered badly from weak signal and high sea waves noise. In processing, over ten iterations of denoise were employed to tackle different types of noise, such as spike, monochromatic, swell, air-blast, linear and random noise.
Prior to implementing Up/Down Deconvolution (UDD) or surface-consistent spiking deconvolution (SCDC), it is necessary to harmonize wavelet characteristics and amplitude RMS originating from diverse terrains, sources, and receivers. This harmonization process ensures the optimal performance of UDD/SCDC in mitigating multiples and enhancing signal uniformity.
Moreover, intertidal data presented unique challenges, in addition to standard processing, we have applied supplementary processing techniques tailored to elevate data quality and facilitate seamless transition from offshore to onshore environments.
With the application of optimum processing workflow, a seamless final image far superior to legacy data was obtained. Multiple content was much reduced due to the longer offsets seismic data and the UDD seismic processing route. Event continuity and fault definition were also improved thanks to the surface-consistent processes (especially SCDC) applied throughout the sequence. Furthermore, most notably, this TZ survey covered areas that had previously never been acquired which are highly prospective.