bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improving Oil-In-Water Treatment by Optimization of Production Chemicals
Authors: Aliti Liridon , Andersen Simon I. 
Published: February 2024

Abstract
The removal of oil droplets from water heavily depends on the ability for these to coalesce into larger drops to overcome size limitation of equipment such as centrifuges, hydrocyclones, gas flotation etc. The composition of PW is a mixture of oily compounds, inorganics from the formation and production chemicals. Chemicals have a significant impact on the stabilization of oil droplets but variations in salinity also plays a role. The repulsion of droplets has detrimental effect on the treatment. In this paper we aim to quantify this in order to develop optimization tools.
Methods, Procedures, Process: The quantification of droplet coalescence and impact of chemistry is obtained through specially designed microfluidic chips. Droplets are recorded using high speed cameras. Using image analysis coalescence efficiency is quantified. Partitioning of chemicals between water and oil which is affected by both salinity and oil type and measured by capillary electrophoresis. This is analyzed using capillary electrophoresis. Real PW samples and chemicals are obtained from offshore Denmark. Coalescence events are recorded while varying oil type and also diluting the PW to understand which constituents lead to stability of drops and hence potential adverse effects in water treatment.
Results, Observations, Conclusions: The fundamental Bancroft´s rule describes that the component favorable dissolved in one phase will stabilize droplets in this continuous phase. Hence compounds primarily soluble in water stabilize oil droplets in the water treatment system, and can lead to poor water quality - potentially having an adverse effect on sizing of equipment. Accordingly specifically water-in-oil (WiO) emulsion breakers can have a detrimental effect when overdosed, as more is not better. When different water streams are commingled before treatment there might be potential cases where one stream despite its apparent low content of oil-in-water (OiW) can stabilize droplets in another stream. We present data based on microfluidics and analysis of partitioning coefficients using a variety of real PWs and production chemicals from O&G production in the Danish North Sea. This clearly indicates that the main issue is related to water constituents, but that oily polar components have a large impact as well on stability. The qualitative information is linked to quantification using the hydrophilic Lipophilic Deviation theory which can then be used to optimize potential scenarios of synergistic and antagonistic effects of chemicals and PW constituents on water quality. Discussion will also aim understanding mixing rules for quantification in multicomponents mixtures based on surface chemical insight.
Novel/Additive Information: We apply both novel microfluidics and novel analytical techniques for production chemical partitioning measurements.
A Graphical User Interface for Hard Rock Drilling Optimization System
Authors: Atashnezhad A. , Al Dushaishi M. F. , Hareland G. 
Published: February 2024

Abstract
The objective of this paper is to present a novel graphical user interface for optimizing drilling operations in hard rock formations. The scope of the study includes presenting the developed Python graphical user interface (GUI) for a hard rock Drilling Optimization System (DOS) that incorporates various models and algorithms to simulate the rate of penetration (ROP) and optimize drilling parameters. The DOS was applied to real-world hard rock drilling data from a deep geothermal well in the Utah FORGE (Frontier Observatory for Research in Geothermal Energy) site. To develop an interactive interface for users, the DOS for hard rock formations was created using the open-source Python library, tkinter. The DOS consists of various hard rock models including PDC ROP, PDC bit wear, drillstring vibration, PDC cutter temperature, mechanical specific energy (MSE), and a differential evolution algorithm (DEA). By integrating these models into the GUI, users can simulate drilling operations, optimize drilling parameters such as weight on bit (WOB) and revolution per minute (RPM), and determine the wear constant of a specific PDC bit. This interactive interface enhances user engagement and facilitates efficient drilling optimization. The study observed an improved ROP and reduced drilling time by optimizing WOB and RPM. The conclusions drawn from this study emphasize the importance of specialized techniques and tools for drilling in hard rock formations and highlight the potential for more efficient and sustainable drilling operations in the geothermal industry. The integration of various models and algorithms within the GUI DOS provides a novel, and practical approach to simulate and optimize drilling parameters. The results and conclusions of this research contribute to the state of knowledge in drilling practices, particularly in the context of optimizing drilling operations in challenging hard rock formations.
Integration Between Different Hydraulic Fracturing Techniques and Machine Learning in Optimizing and Evaluating Hydraulic Fracturing Treatment
Authors: El Khouly I. , Sabet Ahmed , El-Fattah Mahmoud A. A. , Bulatnikov M. 
Published: February 2024

ABSTRACT
Fracture geometry and conductivity are critical parameters for fracture treatment optimization, especially in cases that close to unwanted zones either water-bearing or gas zones. This study investigates the Artificial Neural Network (ANN) model for hydraulic fracturing optimization. The workflow begins with an integrated ANN model, then sets of variable fracture parameters and formation rock properties were utilized for training and testing the ANN based on the most appropriate activation function, the number of hidden layers and the number of neurons.
The ANN model considers a 59 real field data of hydraulic fracturing treatments across the western desert of Egypt. The proposed ANN trained based on pressure transient test analysis that was conducted on the real field data. The available data was divided as 70% for training, 15% for validation, and 15% for testing. The optimum number of hidden layers and neurons was achieved after several trials.
The proposed ANN model result was promising as compared with the common fracture simulation software. The cross plot of the actual fracture geometry parameters versus the predicted ANN outputs showed a good match with the correlation coefficient (R) for the whole data is 0.93. Then the relative importance of the ANN input parameter on the fracture geometry optimization was employed by the Garson method. The result of this work shows the potential of the approach developed based on the ANN model for predicting the fracture geometry.
Completion Optimization by Fracture Mapping Using Realtime High Resolution Resistivity Imaging Tool in Horizontal Wells of Western Offshore India
Authors: Bagga Pawandeep Singh , Chitroda Chandrajyoti 
Published: February 2024

Abstract
The Western Offshore Basin is a significant geological region located along the western coast of India, extending from Gujarat in the north to Maharashtra in the south. It encompasses a vast expanse of the Arabian Sea, where the continental shelf gradually gives way to the deep oceanic waters. This basin is of immense importance in the field of hydrocarbon exploration and production due to its rich reserves of oil and natural gas. The petroleum industry finds horizontal wells highly appealing because they offer a promising solution for enhancing both production rates and recovery efficiency. By drilling horizontal drain holes, the number of wells required to exploit a field can be reduced significantly, thanks to their extensive reservoir exposure. Nevertheless, it is crucial to address the challenges related to completing these wells to extend their operational lifespan.
To optimize oil recovery and prolong the lifespan of a well, horizontal wells need to be completed with an optimal number of Inflow Control Devices (ICDs) that have appropriate Flow Resistance Ratings (FRR). This setup ensures the even distribution of flow along the horizontal well in formations with high permeability. It also helps mitigate early breakthrough at the heel for thin oil formations and delays water breakthrough at locations with high permeability in heterogeneous formations.
Advanced high-definition Logging-While-Drilling (LWD) electrical imaging services has brought a significant breakthrough in subsurface characterization during drilling operations. This cutting-edge technology combines the power of LWD measurements with high-resolution electrical imaging capabilities, offering unprecedented insights into the geological formations surrounding the wellbore. Real-time images are valuable for detecting wellbore stability problems such as drilling-induced tensile fractures and breakout in time to mitigate the problem. Sedimentary steering is also possible with real-time images, letting you keep the wellbore in the best part of the formation.
This paper aims to examine the progress of modern technology in high-definition logging-while-drilling electrical imaging tools. These tools gather micro resistivity data along the entire circumference of the borehole while the bottomhole assembly (BHA) is rotating. The obtained micro resistivity image from LWD, after undergoing processing, effectively revealed the existence of fractures. These fractures were subsequently classified into various zones to determine the optimal ICD completion based on the density of fractures. Geological features such as natural fractures and dissolution features such as vugs are clearly resolved and captured by the high-resolution image acquired using LWD Electrical Image logging tool.
Real-Time Automated Formation Evaluation Using the Integration of Logging While Drilling and Advanced Cuttings Analysis
Authors: Alqunais A. E. , Solial A. J. , Ferriday T. , Collett E. , Taher A. 
Published: February 2024

Abstract
Real-time formation evaluation is performed utilizing data acquired in the field from logging-while-drilling (LWD) tools and mud-logging data equipment. The data is then interpreted in the office by petrophysicists and log analysts. Unlike traditional log interpretation analysis, automated log analysis using statistical models provides continuously improving results based on trained and supervised models. Most automated log analysis approaches utilize historical data and incorporate multi-well data to improve the petrophysical evaluation. The objective is to reduce the evaluation time and reduce uncertainties based on trained models.
Real-time LWD and surface data logging are primarily used for formation evaluation and well placement in high-angle and deviated wells. Log analysis is usually performed by petrophysicists and is not in actual real time. Providing the interpretation in actual real time provides important data for geologists, well placement engineers, and drilling engineers to improve the reservoir contact and productivity in addition to operational cost reduction.
A selection of models has been used for automated lithology predictions. Five logs have been used in total utilizing basic LWD data (gamma ray, density, resistivity, photoelectric, and neutron-porosity measurements). In addition to the LWD data, advanced cuttings analysis has been performed on site in real time on multiple wells. X-ray fluorescence (XRF) provides elemental data while X-ray diffraction (XRD) provides direct mineralogy measurements.
The automated lithology interpretation provides quick assisted lithological interpretation and quantifies uncertainties with minimal human input. Basic LWD data were used for the automated lithology interpretation. The predicted lithology was verified against interpreted mineralogy from XRF and direct mineralogy from XRD measurements. Simulation of the results and the real-time QC process are very promising. Quality control processes were followed for the data acquisition where XRF computed gamma ray was used to verify the depth control for XRF and XRD data with reference to the LWD measurements.
Real-time automated log analysis provides a step change in formation evaluation, providing critical information to well-placement and drilling engineers as well as an automated quality-control measure for data acquired in real time.
Surface and Subsurface Development Strategy of a Carbonate Stringer with Halite Production in Southern Oman
Authors: Kindi I. Al , Bahluli M. Al , Agrawal P. , Alawiya B. Al , Sulaimi G. 
Published: February 2024

Abstract
Stringer reservoirs in south of Oman are carbonate bodies encapsulated in thick zones of Ara salt. The pressure in these reservoirs is varying from lithostatic to hydrostatic regime. Halite production in field HL-3A has been a major challenge throughout the years of production; hence, a thorough investigation was needed to tackle the issue and come up with a strategy to decrease salt migration to the wellbore. Fluid sampling and pulsed neutron logging (PNX) were done to study salt content and free water fraction variations over the well production timeline. Additionally, well testing was performed to identify the suitable offtake envelope to control halite production by monitoring wellhead pressure, water cut, and salt concentration at different choke sizes. Such an approach led to a reliable well offtake envelope to constraint plugging issues caused by salt; the strategy was more sustainable than previous short-term strategies, like regular freshwater flushing. Plus, it contributed to lowering field development cost by 30%. This paper describes actual experience shared from HL-3A reservoir management and learnings. The approach could be beneficial for comparable depletion cases elsewhere and valuable in deferment reduction, field development planning, and halite production management steering to operational excellence.
Enhancing Fluid Characterization in Oil and Gas Exploration: A Global Approach to GOR- Composition Relationship
Authors: Suman S. , li Z , Satapathy P. 
Published: February 2024

Abstract
This research introduces a fluid characterization tool designed for the oil and gas industry, focusing on improving the understanding of fluid composition by correlating Gas Oil Ratio (GOR) and fluid properties.
The tool was developed using a dataset that includes GOR values ranging from 1000 to 6000 scf/stb, bubble point values between 3500 and 5500 psia, and API gravity values from 40° to 55°. This dataset was collected from over 40 wells in the Delaware Basin, ensuring precision and avoiding the manual errors associated with traditional analog tools.
Traditionally, the process involved finding an analog well, a step prone to errors due to variations in proximity and fluid properties. The tool, however, establishes correlations between GOR, fluid properties, and relevant data points, creating an algorithm for deriving reservoir fluid composition. This composition seamlessly integrates into the Global Fluid Characterization (GFC) Model.
The fluid characterization tool proved to be accurate and reliable in characterizing fluid composition. It provided immediate and trustworthy results through its user-friendly interface. With only GOR values, professionals can get a good estimate of reservoir fluid composition. The tool eliminated the need for laborious and expensive laboratory analyses, making it a valuable time-saving and cost-effective solution.
The dataset used for its development, encompassing a wide range of GOR from 1000 scf/bbl to ~5000 scf/bbl. Additionally, the capability of the tool can be enhanced as new wells are incorporated in the Global Fluid Characterization (GFC) Model. It enables us to use compositions for various purposes like making informed decisions in reservoir simulations, well testing, and production activities.
Learnings from Inflow Control Devices (ICD) Design Optimization Utilizing Dynamic Reservoir Simulation Modeling
Authors: Hidayat W. , Karim M. Abd. , Albassam M. 
Published: February 2024

Abstract
The objective of this paper is to present learnings from designing inflow control devices (ICD) of numerous wells at reservoirs with gas cap with various settings. Key aspects and an efficient ICD design workflow will be presented. The evaluation is based on the application of nozzle ICD for single lateral horizontal well. A synthetic simulation model is utilized to demonstrate example cases.
A horizontal well installed with ICD completions improves well performance by equalizing production along the horizontal section to delay water/ gas breakthrough for an oil reservoir with gas cap and aquifer.
We utilized an in-house reservoir simulator with advanced complex well options. The first step is to develop an ICD completion design workflow, which includes understanding reservoir permeability heterogeneity, its magnitude and well flow behavior under open-hole completion. At well level, this step is to estimate future major gas and water contribution. Optimum well rate is sensitized for the ICD design. The next step is to focus on ICD design optimization which includes numbers of ICD requirements and compartments, ICD choking.
The performance of horizontal well placed under a gas cap was analyzed. An early gas production easily occurs especially for well with high production rate. Controlling gas and water production showed an improvement on oil recovery. We developed the workflow of an ICD completion design optimization for the evaluation. Simulation model with different reservoir properties vertically were created for ICD design case. The ICD design optimization cases with combination of these two factors are evaluated to identify conditions for ICD installation that provide best benefits. Results showed that installation of ICD provides good performance improvement and more even gas oil contact and water oil contact movement toward the wellbore.
The ICD design workflow provides a guideline to do the ICD design systematically utilizing reservoir simulation model for an oil rim reservoir. Learnings obtained from the results provide an understanding on the optimal conditions for ICD installation with the goal to ultimately deliver long-life wells while controlling water and gas production in different levels of reservoir heterogeneity and well lengths.
Comparison of Different Type of Acid Diversion in Acid Frac Stimulation and their Effectiveness to Well Production
Authors: Aldawsari Mudhish A. , Ahmed Mutaz M. , Alshoura Basem F. , Wijaya Rio , Vossen Johannes 
Published: February 2024

Abstract
Acid fracturing has been commonly used to stimulate carbonate formation. Presented in this paper are different types of acid diversion techniques used for one such case. This acid diversion is intended for better acid distribution across long stimulation target intervals. The different types of acid diversion techniques that were used include crosslinked acid, viscoelastic based acid diverter, solid and self degradable fiber acid diverter, and Associative Polymer / RPM based acid diverter. The paper is comparing the effectiveness of the diverter and also the effect of the acid diversion to the well production.
The examples that were selected for analysis are producing from the same formation and located relatively close to each other to enable fair comparison. Acid diversion effectiveness is measured based on pressure increase that was observed during the acid fracturing treatment. As the length of stimulation target intervals are different between stages and wells, the pressure increase was then normalized to the length of the perforation / open hole interval. Other than pressure increase, well deliverability post acid stimulation was also compared between wells and was normalized to the reservoir pressure – flowing well head pressure (from available data during well test post acid frac stimulation). These two parameters: normalized pressure increase from acid diversion and normalized maximum gas rate during the well test were then graphed to see the trend between these two parameters.
Different types of acid diversion give different pressure increases during acid diversion. In general, the higher the pressure increase, the higher the maximum gas rate. There’s an optimum point of pressure increase from acid diversion that correlates with maximum gas production, which is observed from the wells that were studied.
The approach described in this paper is intended to provide the guidance on selecting the type of diverter for acid frac stimulation for better well delivery. This approach is formation specific and the completion type needs to be accounted for when designing similar acid fracturing.
Case Studies in Integrated Fracture Design and Well Spacing Optimization in Shale
Authors: Fowler G. J. , McClure M. W. , Singh A. , Irvin R. , Ratcliff D. , Ponners C. , Rondon J. 
Published: February 2024

Abstract
Well spacing and hydraulic fracture design have an enormous impact on the economic performance of wells in shale. Key design parameters include: (a) horizontal and vertical well placement, (b) stage length, (c) cluster spacing, (d) cluster shot count, diameter, and phasing, (e) proppant and fluid type, (f) proppant and fluid volume, and (g) injection rate. Case studies from the Bakken, Delaware Basin, Midland Basin, and Montney shale plays are presented. Numerical simulation is used to evaluate alternative options and maximize economic objectives.
Numerical simulations are performed with a fully integrated hydraulic fracturing and reservoir simulator. Rather than performing a ‘handoff’ between two different codes, the simulator solves all governing equations (for multiphase flow, crack propagation, non-Newtonian fluid, and proppant transport) in a single system of equations and consistent mesh (wellbore, fractures, and matrix). The workflow involves: (a) construction of an initial model, (b) calibration to field diagnostics, (c) and economic maximization with an automated optimization tool. Diagnostics include: (a) fiber DAS and DTS, (b) microseismic, (c) geochemical analysis, (d) interference testing, (e) downhole imaging, (f) production data, and (g) pressure monitoring wells.
Field observations suggest significant variability in fracture geometry between basins. Height growth varies dramatically and is driven by the vertical stress profile. In one dataset, recently developed ‘viscoelastic stress relaxation’ derived stress profiles are much more consistent with fracture geometry observations than the classical Eaton’s approach. Fracture length and effective toughness show a modest degree of variability between formations. Once calibrated, the models enable economic optimization. Optimization runs suggest opportunities to improve NPV (net present value) or DROI (discounted return on investment) from 10-60%. For some parameters (such as job size and well spacing), optimization results vary significantly depending on the objective function (either DROI, NPV, or NPV/section, with or without including the cost of land). The price of oil and gas also have a major impact on the optimal design. For other parameters, such as landing depth, stage length, and perforation cluster design, optimization results are relatively robust to the objective function and economic assumptions. We show how differences between basins and differences in economic inputs and objectives lead to significantly different optimal frac designs.