Hyperbolic rheological model with shear stress limit for acrylamide polymer modified bentonite drilling muds

Vipulanandan, C.; Mohammed, Ahmed Salih

doi:10.1016/j.petrol.2014.08.004

Cited by 140 publications

(41 citation statements)

References 9 publications

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“…where, µ (cP) is viscosity, λ c (s) characteristic relaxation time, [51][52][53], and hydraulic fracturing fluids [54], which compared to the power law based models is also able to predict the rheological behavior of the evaluated fluid at certain experimental conditions, as well as to estimate the maximum stress reached by the tested fluid at relatively high shear rates values. Hence, it was decided to use the Vipulanandan model for describing the breakdown flow curves of the EHO-Carrier-fluid and EHO-Nanofluid systems obtained through the hysteresis loop tests, in order to acquire additional information concerning the distinct EHO rheological properties modification derived from the final formulated carrier fluid and nanofluid addition.…”

Section: Rheological Modellingmentioning

confidence: 99%

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Development of Nanofluids for Perdurability in Viscosity Reduction of Extra-Heavy Oils

Montes

Orozco²,

Taborda

et al. 2019

Energies

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The primary objective of this study is the development of nanofluids based on different diluent/dispersant ratios (DDR) for extra-heavy oil (EHO) viscosity reduction and its perdurability over time. Different diluents such as xylene, diesel, n-pentane, and n-heptane were evaluated for the formulation of the carrier fluid. Instability of asphaltenes was assessed for all diluents through colloidal instability index (CII) and Oliensis tests. Rheology measurements and hysteresis loop tests were performed using a rotational rheometer at 30 °C. The CII values for the alkanes type diluents were around 0.57, results that were corroborated with the Oliensis tests as asphaltenes precipitation was observed with the use of these diluents. This data was related to the viscosity reduction degree (VRD) reported for the different diluents. With the use of the alkanes, the VRD does not surpass the 60%, while with the use of xylene a VRD of approximately 85% was achieved. Dimethylformamide was used as a dispersant of the nanoparticles and had a similar VRD than that for xylene (87%). Subsequent experiments were performed varying the DDR (xylene/dimethylformamide) for different dosages up to 7 vol % determining that a DDR = 0.2 and a dosage of 5 vol % was appropriated for enhancing EHO VRD, obtaining a final value of 89%. Different SiO2 nanoparticles were evaluated in the viscosity reduction tests reporting the best results using 9 nm nanoparticles that were then included at 1000 mg·L−1 in the carrier fluid, increasing the VRD up to 4% and enhancing the perdurability based on the rheological hysteresis and the viscosity measurements for 30 days. Results showed a viscosity increase of 20 and 80% for the crude oil with the nanofluid and the carrier fluid after 30 days, respectively. The nanoparticles have a synergistic effect in the viscosity reduction and the inhibition of the viscoelastic network re-organization (perdurability) after treatment application which was also observed in the rheological modeling carried out with Cross and Carreau models as the reported characteristic relaxation time was increased almost a 20%. Moreover, the Vipulanandan rheological model denotes a higher maximum stress value reached by the EHO with the addition of nanofluids which is derived from the EHO internal structure rearrangement caused by the asphaltenes adsorption phenomenon.

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Section: Rheological Modellingmentioning

confidence: 99%

“…γ (s −1 ) is the shear rate, A (Pa•s) −1 and D (Pa) −1 are model parameters and τ and τ 0 are the shear stress and yield stress respectively. Furthermore, for estimating the maximum stress τ max the next relation is used [51]:…”

Section: Rheological Modellingmentioning

confidence: 99%

Development of Nanofluids for Perdurability in Viscosity Reduction of Extra-Heavy Oils

Montes

Orozco²,

Taborda

et al. 2019

Energies

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“…The Bingham-plastic model is one of the conventional rheological models widely used for drilling fluids (Maxey, 2007;Vipulanandan and Mohammed, 2014). This model can determine the yield point exhibited by most drilling fluids and cement slurries to predict the minimum force needed for the fluid to start flowing (Vipulanandan and Mohammed, 2014;William et al, 2014). This value is referred to as the Bingham yield point, 0 τ (Khalil and Badrul, 2012b;Khalil et al, 2011).…”

Section: Density and Rheological Measurementsmentioning

confidence: 99%

Lightweight biopolymer drilling fluid for underbalanced drilling: An optimization study

Lim

Khalil

Jan

et al. 2015

Journal of Petroleum Science and Engineering

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“…The Bingham plastic, power-low, and Herschel-Bulkley models are the fundamental models to describe the behavior of drilling mud [2]. Moreover, Vipulanandan [31] and 3 Geofluids hyperbolic models [32,33] have been used for the same purpose recently. However, drilling fluid is generally considered to be classified as Bingham plastic in the drilling industry and the rheological properties of drilling mud are determined based on this model [20,34].…”

Section: Determination Of Rheologicalmentioning

confidence: 99%

The Rheology and Performance of Geothermal Spring Water-Based Drilling Fluids

Avcı

Mert

2019

Geofluids

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In this study, the rheological properties and performances of mud prepared with geothermal spring water to be used by geothermal drilling operators were examined at ambient and elevated temperatures. In this context, mud samples were prepared in the compositions detailed in the API specification by using five different geothermal spring water types and a distilled water type. Afterwards, density, apparent viscosity, plastic viscosity, yield point, gel strength, fluid loss, pH, and filter cake thickness of these samples were measured. The drilling muds were analyzed by means of rheological tests in accordance with the standards of the American Petroleum Institute (API). The experimental results have revealed that the mud prepared with geothermal water have lower viscosity and yield point compared to those prepared with freshwater at elevated temperatures. The stability of the muds decreases, especially at temperatures higher than 250°F, and they start to become flocculated. It was concluded that geothermal water-based muds have higher API fluid loss and cake thickness than the freshwater-based one. Therefore, it could be interpreted that the muds prepared with geothermal spring water will exhibit lower flow performance and lower ability of hole cleaning and rate of penetration compared to the freshwater muds. Hence, it is recommended that this kind of water should not be used to prepare drilling mud.

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Hyperbolic rheological model with shear stress limit for acrylamide polymer modified bentonite drilling muds

Cited by 140 publications

References 9 publications

Development of Nanofluids for Perdurability in Viscosity Reduction of Extra-Heavy Oils

Development of Nanofluids for Perdurability in Viscosity Reduction of Extra-Heavy Oils

Lightweight biopolymer drilling fluid for underbalanced drilling: An optimization study

The Rheology and Performance of Geothermal Spring Water-Based Drilling Fluids

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