Micro-rheometer for inline oil quality detection

The overall goal of this study is to develop thickness shear mode (TSM) resonators for the real-time, label-free, non-destructive sensing of biological adhesion events in small populations (hundreds) of neurons, in a cell culture medium and subsequently in vivo in the future. Such measurements will enable the discovery of the role of biomechanical events in neuronal function and dysfunction. Conventional TSM resonators have been used for chemical sensing and biosensing applications in media, with hundreds of thousands of cells in culture. However, the sensitivity and spatial resolution of conventional TSM devices need to be further enhanced for sensing smaller cell populations or molecules of interest. In this report, we focus on key challenges such as eliminating inharmonics in solution and maximizing Q-factor while simultaneously miniaturizing the active sensing (electrode) area to make them suitable for small populations of cells. We used theoretical expressions for sensitivity and electrode area of TSM sensors operating in liquid. As a validation of the above design effort, we fabricated prototype TSM sensors with resonant frequencies of 42, 47, 75, and 90 MHz and characterized their performance in liquid using electrode diameters of 150, 200, 400, 800, and 1,200 μm and electrode thicknesses of 33 and 230 nm. We validated a candidate TSM resonator with the highest sensitivity and Q-factor for real-time monitoring of the adhesion of cortical neurons. We reduced the size of the sensing area to 150–400 μm for TSM devices, improving the spatial resolution by monitoring few 100–1,000s of neurons. Finally, we modified the electrode surface with single-walled carbon nanotubes (SWCNT) to further enhance adhesion and sensitivity of the TSM sensor to adhering neurons (Marx, 2003).

Transient pressure behavior of Bingham non-Newtonian fluids for horizontal wells

The influence of the non-Newtonian properties of blood on the flow in large arteries: unsteady flow in a 90° curved tube

Heat Transfer to Newtonian and Non-Newtonian Fluids in Rectangular Ducts

Simple Non-Newtonian Fluid Flows

Unsteady flow of a viscous incompressible electrically conducting non-Newtonian power- law fluid near the forward stagnation point of a two-dimensional body in the presence of a magnetic field is studied by means of an analytic technique, namely, the homotopy analysis method. Accurate analytic approximations are obtained, which are uniformly valid for all dimensionless time in the whole region 0 ≤ η< ∞. Effects of integral power- law index of the non-Newtonian fluids for κ =1 , 2, 3 and magnetic number M ≤ 10 on the flow are considered. To the best of authors' knowledge, such kinds of analytic solutions have been never reported. Introduction. Non-Newtonian fluids are very important fluids, which are widely used in industry. Most particulate slurries (china clay and coal in water, sewage sludge, etc.), multiphase mixtures (oil-water emulsions, gas-liquid disper- sions, such as froths and foams, butter) are non-Newtonian fluids. Further exam- ples, including a variety of non-Newtonian characteristics, include pharmaceutical formulations, cosmetics and toiletries, paints, synthetic lubricants, biological fluids (blood, synovial fluid, saliva), and foodstuffs (jams, jellies, soups, marmalades). Indeed, behaviours of the non-Newtonian fluids are so widespread that it would be no exaggeration to say that the Newtonian fluid behaviours are an exception rather than the rule. Since the non-Newtonian fluids have more complicated equa- tions that relate the shear stresses to the velocity field than the Newtonian fluids have, additional factors must be considered in examining various fluid mechanics (see, Irvine and Karni (1)). Several models have been proposed to describe the non-Newtonian behaviour of fluids. Among these models, which are known to follow the empirical Ostwaald- de Waele model, the so-called power-law model, in which the shear stress varies according to a power function of the strain rate, has received wide acceptance. Boundary layer assumptions were successfully applied to this model and much work has been done on it. Schowalter (2) and Acrivos et al. (3) initially theoretically analyzed the steady boundary layer flow of incompressible non-Newtonian power- law fluids and found the existence of the similarity solutions. Kim et al. (4) made a detailed analysis to obtain possible similarity solutions of the steady boundary layer equations of a non-Newtonian fluid. Yukselen and Erim (5) considered the curvature effects on the boundary layer of a non-Newtonian fluid. Thompson and Snyder (6), and Kim and Eraslan (7) investigated the effect of wall mass injection on the flow of a non-Newtonian power-law fluid over a flat plate, near a stagnation point and past a wedge. Akcay and Yukselen (8) analyzed the boundary layer of a non-Newtonian fluid flow with fluid injection on a semi-infinite flat plate, which moves with a constant velocity in the direction opposite to that of the

Fracturing fluid viscosity has an important influence on the outcome of any hydraulic fracturing treatment. Much work has been done on the effect of sand or particle concentration on the viscosity of Newtonian fluids. Work concerning the effects of proppant concentration on the apparent viscosity of non-Newtonian fracturing fluids is now beginning to appear in the literature. Several correlations involving the effects of proppant or particle concentration in non-Newtonian fluids have been presented recently.1–5 This work presents an assessment of influence of proppant on fracturing fluid viscosity using the friction pressure properties of sand-laden non-Newtonian fracturing fluid compared to the friction pressure of the fluid without proppant. For this presentation, the premise is offered that viscosity effects due to the suspended particles in non-Newtonian fluids'should be correlatable when comparing fluid pressure behavior of these fluids in turbulent flow. Correlations have been worked out to describe the effects of sand concentration on effective fluid viscosity. These results compare favorably to the results obtained by other investigators addressing the problem using different techniques.

Effect of temperature on sandstone acidizing using non-Newtonian fluids

Heat transfer in hydrophobic microchannels: lattice Boltzmann analysis of partial magnetic field effects on non-Newtonian fluid dynamics

A comprehensive theoretical study has been carried out on the flow behavior of both single and multiple phase non-Newtonian fluids in porous media. This work is divided into three parts: (1) development of numerical and analytical solutions; (2) theoretical studies of transient flow of non-Newtonian fluids in porous media; and (3) applications of well test analysis and displacement efficiency evaluation to field problems. A fully implicit, integral finite difference model has been developed for simulation of non-Newtonian and Newtonian fluid flow through porous media. Several commonly-used rheological models of power-law and Bingham plastic non-Newtonian fluids have been incorporated in the simulator. A Buckley-Leverett type analytical solution for one-dimensional, immiscible displacement involving non-Newtonian fluids in porous media has been developed. Based on this solution, a graphic approach for evaluating non-Newtonian displacement efficiency has been developed. The Buckley-Leverett-Welge theory is extended to flow problems with non-Newtonian fluids. An integral method is also presented for the study of transient flow of Bingham fluids in porous media. In addition, two well test analysis methods have been developed for analyzing pressure transient tests of power-law and Bingham fluids, respectively. Applications are included to demonstrate this new technology. The physical mechanisms involved in immiscible displacement with non-Newtonian fluids in porous media have been studied using the Buckley-Leverett type analytical solution. The results show that this kind of displacement is a complicated process and is determined by the rheological properties of the non-Newtonian fluids and the flow conditions, in addition to relative permeability data. In another study, an idealized fracture model has been used to obtain some insights into the flow of a power-law fluid in a double-porosity medium. For flow at a constant rate, non-Newtonian flow behavior in a fractured medium is characterized by two-parallel straight lines on a log-log plot of injection pressure versus time. Transient flow of a general pseudoplastic fluid has been studied numerically and it has been found that the long time pressure responses tend to be equivalent to that of a Newtonian system.

Drag reduction is a well known phenomenon. Possible mechanism deduced from heat transfer has been suggested earlier for non isothermal Newtonian fluid treated with polymer drag reducer. Several works have shown the susceptibility of the long chain polymer to shear degradation, hence reduction in its performance. Most of the works were performed in isothermal conditions. Moreover, it mostly covers water soluble polymers. There is an increasing need to address the shear degradation phenomenon for oil soluble polymer, where its performance is related to increase transportation capacity of pipeline as well as energy savings. In this work the degradation of oil drag reducing polymer in a non-isothermal environment in which rheological change of oil (the carrier fluid in this work) occurs as the fluid is transformed from Newtonian to non-Newtonian is addressed. In another words, the paper addresses the temperature effect on the degradation of the oil soluble drag reducer polymer in a wide range of temperatures. The non-Newtonian fluid behaviour here is defined as the temperature below which paraffin deposits in presence of drag reducer polymer. The validity of equations for estimating Colburn factor is also addressed.

Author index

In this contribution we demonstrate the feasibility of a sensor system for viscosity and concentration measurement of complex liquids, in particular suspensions of silicon dioxide particles in water. The sensor system is based on a doubly clamped micromachined beam vibrating in the sample liquid, and an optical readout utilizing a DVD player pickup head. The vibrating beam features resonance frequencies in the range of several 10 kHz, and higher mechanical amplitudes than microacoustic sensors, e.g., quartz thickness shear mode (TSM) resonators or surface acoustic wave (SAW) devices. We show that the damping of the beam is dominated by the viscosity of the liquid, and that this relation also holds for the considered complex liquids, whereas a TSM resonator sensor fails to detect the steady state shear viscosity of the suspensions.

Polymer Fluid Mechanics

This study examines the displacement of non-Newtonian fluid invasion in naturally fractured reservoirs (NFR) by employing the evaluated diffusivity solution proposed by Keshavarz, M., &amp; Moreno, R. B. Z. L. (2023)1,for a comprehensive quantitative analysis. The solution is capable of considering not only drilling fluid pseudo-plasticity throughout the fractured but also the matrix system under constant wellbore pressure assumptions. The effects of non-Newtonian fluid parameters and NFR characteristics on fluid flow, leak-off phenomenon, and cumulative volume are examined. The developed solution generates type-curves for quantitative analysis, it validated by field data of loss measurements in a fractured well in the Gulf of Mexico. Parametric analysis reveals that drilling fluid pseudo-plasticity significantly impacts cumulative volume and ROI (radius of invasion) in NFRs with higher differential pressure, leak-off (particularly at earlier times), and larger fracture apertures. Additionally, the procedure allows operators to determine the ROI for equivalent starting and ending times of the transient period. The proposed solution, applicable to well-completion, enhanced oil recovery (EOR) processes, NFR characterization, and drilling operations, facilitates quantitative analysis of reservoir properties and cumulative volume in NFRs. It also assists operators in optimizing drilling fluid rheology in each period, reducing mud loss or enhancing volumetric sweep efficiency in polymer flooding cases. INTRODUCTION Non-Newtonian fluid flow through naturally fractured reservoirs (NFR) has received considerable attention over the last decades in both experimental and modeling research (Yi, 2004; Adenuga et al., 2019), as it controls important technological processes in petroleum and geotechnical engineering. The viscosity of such fluids has a non-linear relationship between shear stress and shear rate. Polymer solutions, heavy (waxy) crude oil, and drilling fluid are common examples of such fluids in petroleum; thus, they have been used for many years as fracturing agents, drilling fluids, and in some enhanced oil recovery processes (Ikoku &amp; Ramey, 1979; Odeh &amp; Yang, 1979; Garcia-Pastrana et al., 2017; Elkatatny et al., 2020; Albattat &amp; Hoteit, 2021; Albattat et al., 2022; Pang et al., 2022). Even though their application is not novel, the subject of transient flow of non-Newtonian fluids in NFR is critical for improving the accuracy of total cumulative volume measurement and well testing (Ikoku &amp; Ramey, 1979; Escobar et al., 2011; Dokhani et al., 2020). When fluids, flow through porous rocks, pressure behavior is affected by fluid rheology, reservoir architecture, reservoir type, and wellbore condition. NFR has been idealized as double porosity reservoir. The governing equation of the fluid for this type of reservoir is modeled considering flow regime and the geometry of the reservoir. While well test analysis involving the flow of Newtonian and non-Newtonian fluids in single and double-porosity reservoirs under wellbore constant rate has been extensively studied (Odeh &amp; Yang, 1979; Da Prat, 1990; Dake, 2001; Escobar et al., 2011), none of these studies considered wellbore condition constant pressure, to measure non-Newtonian fluid rate and cumulative volume. The basic partial differential equation for newtonian fluid flow in NFRs are originally presented and solved under wellbore constant rate by Warren &amp; Root et al (1963). The case was then studied and solved by Da Prat (1990), under constant wellbore producing pressure. Ikoku &amp; Ramey et al. (1979) proposed a model characterizing homogeneous reservoirs with presence of a non-Newtonian (pseudoplastic) fluid. Olarewaju et al. (1992), was the first to develop an analytical solution for the transient behavior of dual-porosity formations containing a non-Newtonian pseudoplastic fluid. More than a decade later, Escobar et al. (2011) developed and successfully tested a methodology (based on solution presented by Olarewaju et al. 1992) for the interpretation of pressure tests in heterogeneous formations bearing a non-Newtonian fluid, based on the pressure and pressure derivative plot; as a result, they presented new equations for estimation of NFR parameters, which was later modified by Garcia-Pastrana et al (2017). Therefore, the focus of this research is on developing the applicability of evaluated solution presented by Keshavarz, M., &amp; Moreno, R. B. Z. L. (2023) for the diffusivity model, which is solved under wellbore constant pressure and is applicable for cumulative fluid measurement. This evaluated solution has been applied as reference model due to considering dimensionless matrix contribution in pseudosteady-state inter-porosity transfer as the assumption of the dual porosity model. To the best of the Author's knowledge, no study has utilized an evaluated non-Newtonian dual porosity model to measure cumulative volume through NFR while taking leak-off into account. In this regard, evaluated dimensionless rate and cumulative volume solutions in Laplace domain were applied for radial flow of non-Newtonian pseudoplastic fluids in infinite dual-porosity reservoirs. The solutions were numerically inverted by Stehfest et al (1970) algorithm, followed by the formulation of dimensionless terms and generation of type curves to facilitate quantification of parameters in real time.