bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improved Operational Capital Allocation Strategies by Quantifying Inflation and Supply Chain Impacts
Authors: Sharma Akash , Emanuel Jeff , Chapman Mark A. , Godwin Jonathan 
Published: October 2023

Abstract
Asset planning is a critical and complex part of the oil and gas industry, further complicated by recent inflationary and supply chain issues. The present paper focuses on these challenges and recommends an integrated approach incorporating service market fundamentals, commodity fundamentals, cost inflation, and sensitivity analysis to better plan asset development and capital deployment via service cost modeling. Successful oil and gas operations require the sourcing of a variety of complex goods and services. Each of these may have similar or different market factors impacting their pricing performance. The present paper tackles this challenge by leveraging a multivariate regression modeling approach. This modeling technique establishes relationships between raw cost drivers like the WTI Prices, steel cost, labor, etc. and cost of oilfield materials, goods, and services. These costs are sourced as aggregated information of transactional prices to maximize accuracy. We then present quantitative forecasts for these prices and how they impact the overall well and asset cost.
The resulting model provides critical insights into key oil and gas operational goods and services and their correlation with key market factors. By incorporating time-based optimization, the lags between market drivers and their impact on cost can also be understood. The models all showed significant predictability with R-squared values greater than 0.75. The authors find that this approach will help companies make informed decisions about contract and procurement strategies to improve their bottom line. The paper presents a novel approach to asset planning capital allocation by incorporating market and commodity fundamentals, cost inflation, and sensitivity analysis into a multivariate regression modeling framework for service cost forecasting. The resulting model provides valuable insights into the key operational commodities and their correlation with key market factors, enabling companies to make more informed decisions about asset planning.
A Comprehensive Review of Screen Plugging During Openhole Sand Control Completions Installation; Causes, Consequences and Best Practices
Authors: Beldongar Maye , Gadiyar Bala , Jeanpert Julie , Whaley Kevin , Jackson Philip , Carpineta Gabriele , Luppina Salvatore , Farina Lisa , Giammancheri Michele 
Published: October 2023

Abstract
In openhole completions, screens are one of the very common equipment used to control production of solids. Screens could get plugged during installation in case of improper wellbore fluid conditioning and displacement. Awareness of screen plugging is not widely spread and many practicing engineers do not pay enough attention to its implications. This paper will discuss the causes, consequences, ways of determining plugging and recommend best practices to the reduce risk of screen plugging.
The paper will first review the various reasons for screens to get plugged during openhole completion installations and explain in detail undesirable events caused by screen plugging such as:
Inability to properly displace wellbore fluids Inability to fully pack the screen annulus Damage to screens during displacement and gravel packing
It will also review downhole gauge data of several jobs to identify and discuss screen plugging signatures and its outcomes. Additionally, the paper will discuss potential preventive measures.
In openhole completions, it is very common to run screens in wellbores containing solid laden fluids intentionally or unintentionally. Poor wellbore displacement or improper fluid conditioning can result in leaving some bigger size solids in the screen running fluid which could plug the screens. Also, the exposure of reactive shales to water base fluids can destabilize the shales and lead to plugging. In some cases, the screen running fluid quality control (QC) is not properly accounting for the actual flow inside the screen while running in hole resulting in a false pass.
The paper will present several case histories of downhole gauge data analysis showing evidence of screen plugging leading to excessive treating pressure, incomplete gravel pack and in few cases screen erosion during gravel pack operations. To prevent screen plugging it is necessary to properly model all the displacement stages, pay attention to proper conditioning and QC of the fluid and ensure compatibility of the fluids with shales.
A comprehensive review of screen plugging during sand control installation phase and its potential consequences supported with extensive downhole gauge data has not been previously published. This paper will be a valuable source of knowledge for completion engineers and help them better design and executed future operations.
Deep-Learning-Based Approach for Optimizing Infill Well Placement
Authors: Zhang P. , Gao T. , Fu J. , Li R. 
Published: October 2023

Abstract
This study introduces a novel machine learning-based framework aimed at optimizing well placement for shale development. Traditional well-placement techniques, often reliant on physics-based modeling or empirical assumptions, have proven to be time-consuming and prone to suboptimal results. To address these limitations, we propose a Deep Convolutional Neural Networks (DCNN) based workflow that leverages context-specific algorithms for accurate subsurface-driven infill planning optimization. The framework was validated on real-world data from 2 fields of 630 wells in the Permian basin, successfully replicating the validation dataset with 94% accuracy and reducing the time required for analysis by over 85% compared to conventional methods. Furthermore, the framework demonstrated improved Estimated Ultimate Recovery (EUR) and effective reserve management, emphasizing its potential to enhance the economic viability of shale production.
Feasibility Study of Electromagnetic Telemetry System for Offshore Drilling
Authors: Zeng Shubin , Ashraf Tauseef , Zhang Jun , Huang Yueqin , Chen Jiefu 
Published: October 2023

Abstract
Electromagnetic telemetry (EMT) system uses a downhole source inserted near the drilling bit to send out real-time measurements via low frequency electromagnetic waves. A surface antenna picks up the transmitted signal by measuring the potential difference of two locations. Compared with onshore drilling, EMT system for offshore drilling has two major differences: there exists one layer of conductive seawater and one endpoint of the surface antenna anchors near the seabed. An integral-equation-based simulation algorithm was developed for fast and accurate simulation of EMT system in oil and gas exploitation. How the conductive seawater affects electromagnetic wave propagation is studied by modeling different scenarios by changing water depth, well trajectory, downhole source type, and operating frequency. The success of EMT application is strongly dependent on the formation resistivity between the downhole tool and the surface antenna used to monitor the transmitted signal from the downhole tool. Therefore, it’s important that an accurate prediction of the EMT system performance is performed before planning and performing an EMT job. Theoretical and numerical analysis suggests that EMT technology for offshore drilling behaves differently from onshore drilling because there exists a layer of conductive seawater and the surface antenna must traverse through the seawater to the seabed.
An Analytical Tool to Predict Fracture Extension and Elastic Desaturation for Polymer Field Projects
Authors: AlAbdullah M. B. , Seright R. S. , Machado M. V. B. , Delshad M. , Sepehrnoori K. 
Published: October 2023

Abstract
Induced fractures often play a key role in achieving acceptable injectivity during polymer floods, especially for vertical injection wells. However, fracture extension must be controlled to prevent severe channeling between the wells and compromise the flood performance. This paper presents a physics-based analytical model to predict polymer injectivity and fracture length as a function of polymer rheology, injection rate, and reservoir geomechanical properties. The analytical injectivity model is based on the unified viscoelastic model by Delshad et al. (2008). The injectivity model is coupled with 2-D fracture models: Perkins-Kern-Nordgren (PKN) and Kristianovich-Geertsma- de Klerk (KGD). In addition, the model is coupled with the elastic desaturation curve to predict additional oil recovery due to polymer viscoelasticity as a function of the leak-off rate through the fracture faces. Finally, a sensitivity study is conducted on reservoir properties and polymer rheology to understand the dominant factors that control fracture extension.
The analytical model shows good agreement in injectivity and fracture length with two other fracture numerical simulation models (Gadde and Sharma 2001, Ma and McClure 2017). The degree of fracture extension is a strong function of formation permeability, with relatively short fractures predicted for the high permeability characteristics of most commercial-scale polymer floods. We also examine conditions when relatively high leak-off rates through fracture faces might allow the viscoelastic nature of HPAM solutions to displace capillary-trapped residual oil. This is the first analytical solution for coupled polymer injectivity and fracture-length based on real HPAM rheology that can be used by a simple mathematical software or Excel worksheet. The developed tool can assist field operators in reducing the uncertainty and risk in polymer injectivity and quantifying fracture extension in the reservoir.
The Impact of the Energy Transition on Petroleum Engineering Departments: The Faculty Perspective
Authors: Fahes M. , Hosein R. , Zeynalov G. , Karasalihovic Sedlar D. , Srivastava M. , Swindell G. S. , Kokkinos N. C. , Willhite G. P. 
Published: October 2023

Abstract
We live in a time where there are a lot of conversations regarding transitioning energy systems from a major dependance on fossil fuels towards more reliance on renewable energy sources. Such a transition, no matter the pace and shape it takes, has a direct impact on petroleum engineering education. In this paper, we share the results of a world-wide survey that targeted capturing the perspectives of faculty members regarding the impact of the current state of affairs on petroleum engineering education. We analyze those results under various contexts, which include observing the perspectives and impacts by region, age group, and sex. The questions probe the perception of the faculty members regarding how long fossil fuels will remain a major part of the energy mix, the impact this has on their ability to fund their research and publish their work, the impact on recruiting students and on strategic directions in the academic programs, and what the faculty need in order to maintain a curriculum that is relevant to the future careers of their students.
The results reveal that the vast majority of faculty see in the energy transition an opportunity for change in petroleum engineering education. Over 95% of respondents support covering the topics of environmental sustainability, clean energy, and data analytics in the undergraduate petroleum engineering curriculum, with the majority suggesting data analytics be covered as a mandatory course, clean energy as optional electives, and environmental sustainability be included to supplement existing courses. Most faculty are willing to invest the time and effort needed to make the necessary changes to the curriculum, but many do not feel prepared to make some of those changes. The resources faculty identify as useful to be made available to them include well-designed in-person networking events with industry professionals and facilitated learning communities for petroleum engineering faculty. There is no overwhelming support for changing the name of the degree, and most faculty believe that the change should be a process of continuous improvement rather than undergoing a major disruption. There is variability by region in the impact the current challenges have had on industry support for academic research, and variability by age group regarding how long fossil fuels will remain relevant.
New Insights on Catalysts-Supported in situ Upgrading of Heavy Oil During in situ Combustion Oil Recovery
Authors: Fassihi M. R. , Moore R. G. , Pereira Almao P. , Mehta S. A. , Ursenbach M. G. , Mallory D. G. 
Published: October 2023

Abstract
As part of GHG reduction initiatives, there have been many publications on CO2 capture, utilization, and storage (CCUS), reducing the carbon footprints in the oil and gas production, switching to renewable energies, and generating carbonless fuel (e.g., H2) via in situ processes. In situ upgrading of bitumen and heavy oils and converting them into low sulfur, low N2, and low asphaltene can help with both producing cleaner fuel as well as utilizing vast resources of energy that could otherwise be wasted due to extreme measures of no fossil fuel policies. Additionally, such processes could produce valuable products, enhanced shipping/pipelining, and less demanding downstream processing. Generating hydrogen could be another focus area for in situ upgrading.
This paper provides new insights into the results of several combustion tube tests that were performed for Alberta Ingenuity Centre for In Situ Energy (AICISE) using different heavy oils with fresh supported catalyst. The catalysts were placed in the production end of the combustion tube so oil would pass over the catalyst bed before being produced. In practice, solid catalyst particles could be placed into the oil-bearing formation adjacent to the producing wellbore, ensuring that crude oil will flow over the catalysts during oil production. This paper utilizes many of the lab results that have never been published before. The objective is to understand whether using catalysts has merits in our future oil production activities under the current environmental restrictions. A commercial Ni/Mo catalyst was used in these tests. The results of these tests indicated at least temporary significant occurrence of reactions such as: hydroprocessing (HP), hydrotreating reactions, such as hydrocracking (HC), hydrodesulfurization (HDS), hydrodenitrogenation (HDN) and hydrodeoxygenation (HDO).
We will discuss the impact of pressure, temperature, water injection and dispersed versus supported catalysts on the degree of oil upgrading. Also, the key parameters that could impact in situ hydrogen generation will be presented. Specifically, the role of reactions such as Aquathermolysis (AQ), thermal cracking (TC), water-gas shift reaction (WGS) and coke gasification (CG) will be discussed. Notice that the products of these reactions could undergo additional methanation reactions (ME) which could reduce the H2 concentration in the produced gas. Finally, methods of upscaling these results to the field conditions will be presented.
Efficient Deployment of Distributed Temperature and Acoustic Sensing of Three Wells Using Fiberline Intervention Technology
Authors: Alaseri Ghassan , Bukhamsin Ahmed , Garioch Andrew , Abdulghani Ahmed 
Published: October 2023

Abstract
Fiber optics has been an emerging technology in the oil industry as it provides critical downhole data from the well. However, running fiber in the well has been mainly limited to new constructions or through costly coiled tubing operation. This paper describes a novel method to deploy fiber in existing wells and collect distributed and single-point data. This was demonstrated through a successful and low-cost logging operation.
FiberLine Intervention (FLI) employs a unique conveyance method to deploy the fiber inside the well. Two fibers (single-mode and multi-mode) with total length of more than 25,000ft have been wound inside a tool length of around 3ft, which can then unspool from the tool as it drops down the well by gravity. The tool utilizes bare optical fiber and housing materials that will degrade in the well, so it does not disturb production after completing the job.
The end of the fiber is equipped with an electronic gauge to measure single point pressure while the fiber itself can be interrogated to provide Distributed Temperature Sensing (DTS) and Distributed Acoustic Sensing (DAS) data. Real-time data monitoring capability is enabled by connecting the top of the fiber to a surface laser box.
Normal practice to deploy sensing and monitoring logging tools is to use slickline or wireline. Operational costs and time are of particular concerns, especially when there is a need to bring rigging equipment. Regarding this matter, FLI technology surpassed the conventional slickline by consuming only 15 minutes from releasing the electronic probe to reach the hold-up depth. During this time, DTS, DAS, pressure and temperature data were recorded in real-time. The location of the tool could be confirmed by the fiber loss plot, which shows excessive losses in the still spooled fiber within the probe, and normal losses in the fiber deployed in the wellbore. After the tool has reached the target depth, the annuli were bled of and the DAS responses were monitored to check for any leak in the completion.
The presented field trial represents a successful logging operation, starting from tools setup to the data quality. This breakthrough could be viewed as a starting point as further developments can consider using this as a platform to deploy more variety of sensors downhole.
Attention Mechanism Neural Network for Seismic Facies Classification
Authors: Ang C. T. , Sajid M. , Elsheikh A. , Alsalmi H. 
Published: October 2023

Abstract
Identifying seismic facies groups from seismic data includes tasks such as interpreting structures and assigning facies information into the identified structures. The process of seismic interpretation relies on expert interpretation and is generally time consuming. In the current work, we develop a new network architecture for automatic seismic facies class with attention mechanism for improved classification results.
Overcoming the Obstacle of Reservoir Stimulation Through ICD Completion - The First Approach of Valvular Conduit for Inflow and Outflow Control Devices
Authors: Nugraha Ikhsan , Siham Ahmed , Widjaja D. , Nasir H. A. 
Published: October 2023

Abstract
Horizontal wells often require production control along the open hole. This is achieved by installing appropriate Inflow Control Devices (ICD) configurations that introduce higher restrictions across flow dominant zones and less restrictions across poorer quality zones respectively. Although these restrictions are designed to allow normalized production across the entire horizontal section, it can adversely impact the control of injection rates across the horizontal section during acid stimulation jobs. This paper intends to discuss a new approach to overcome these limitations and allow injection of the desired rates resulting in more effective acid stimulation works.
To overcome injection rate limitation during stimulation, a new valvular conduit flow profile was tested for ICD application. It relies on dynamic diversions and collisions of the fluid flow in series to provide restrictions, hence pressure drop. The valvular conduit geometries were adjusted to achieve desired flow restrictions that are equivalent to nozzle ICD in production direction. When the flow is reversed, valvular conduit profile ICD significantly reduces fluid diversions and collisions resulting in higher rate in injection direction for the same applied pressure drop.
These unique features were taken into ICD near wellbore modelling workflow in conjunction with available well and reservoir properties to evaluate its performance and operating envelope. Furthermore, stimulation model was studied for the new completion impact on fluid distributions as well as acid penetration in to the reservoir matrix.
Improvement of Polymer Flooding of a Viscous Oil by Addition of an Alkali
Authors: Guo Yujia , Shi Yue , Mohanty Kishore 
Published: October 2023

Abstract
Polymer flooding has been applied successfully in many water-wet, viscous oil reservoirs. When the reservoir is intermediate-wet or oil-wet, the polymer dosage has to increase to keep the displacement front stable, which adds to the cost. Alkali can generate in-situ soap, which lowers interfacial tension and may change wettability; therefore, alkali-polymer (AP) flood can be considered as an alternative way of improving recovery without increasing polymer concentration. This work studies the effect of alkali addition to polymer floods in displacing viscous oils from sand packs and carbonate packs of various wettability. Sessile drop contact angle (SDCA) and water drop penetration time (WDPT) measurements were conducted to evaluate the wettability before and after alkali treatments. The floods were conducted in a custom-designed 2-D visualization cell. The results show that the alkali was able to reduce the IFT between the viscous oil and water to 0.07 dyne/cm. SDCA and WDPT results showed that the sand pack with an initial water saturation (Swi) tends to be water-wet, while that without Swi tends to be intermediate-wet. The carbonate pack was tested to be strongly oil-wet even at Swi. Alkali was effective in making the intermediate-wet sand more water-wet, but has a limited effect on the oil-wet carbonate. Coreflood results show that in water-wet sand packs, the AP flood with a viscosity ratio of 10 results in a stable displacement with an incremental oil recovery of 7% OOIP compared to the straight polymer flood of the same viscosity ratio. In intermediate-wet sandstone packs, the AP floods were unstable, and early breakthrough was observed. However, the oil recovery of AP floods was still 5% higher than the straight polymer flood at 2 PV. AP flooding in oil-wet carbonate packs recovered 18% additional oil at 2 PV injection than the polymer flood at the same viscosity ratio. This study suggests that the efficiency of polymer foods can be improved by addition of an alkali.