Modeling Apparent Viscosity, Plastic Viscosity and Yield Point in Water-Based Drilling Fluids: Comparison of Various Soft Computing Approaches, Developed Correlations and a Committee Machine Intelligent System

Abstract In deepwater drilling, the rheology of traditional drilling fluid is uncontrollable since the fluid usually mixes with brine and encounters low temperature. A solution may be to use the newly designed brine-based fuzzy-ball drilling fluids (BFDFs) since these have a well-adapted rheology under high salinity and low temperature condition. This has the potential to make drilling safer and more efficient. In this experiment, the rheological properties of BFDFs under test conditions were characterized with a rheometer by varying salinity (2 to 20 mass%) and temperature (4 to 80 °C). The rheological parameters considered are apparent viscosity (AV), plastic viscosity (PV), yield point (YP), and θ6 reading. To characterize the magnitudes of changes of the rheological parameters and their low temperature dependence, their ratios at 4 and 25 °C, and 4 and 80 °C were calculated. The results showed that the apparent viscosity (AV), the plastic viscosity (PV), the yield point (YP), and θ6 reading of BFDFs increased slightly with the decrease of salinity and temperature. The ratios of rheological parameters at 4 and 25 °C were close to unity, while the ratios at 4 and 80 °C were about two. The flow behavior of BFDFs under high salinity and low temperature condition was stable. Therefore, brine could be used as the base fluid for BFDFs. Theoretically, the flow behavior of BFDFs under low temperature condition seems to follow the Herschel-Bulkley model. Practically, the tests indicated that the BFDFs possess a strong tolerance to sandstone cuttings and Cabentonite, an excellent inhibitive property to shaly cuttings, weak corrosive characteristics against N80 casing steel, excellent lubricity properties, and remarkable biodegradability. In summary, the empirical results showed that the newly designed fuzzy-ball working fluid can use brine instead of fresh water as based fluid and maintain remarkable properties under high salinity and low temperature condition. Properties of BFDFs could basically satisfy the requirement of deepwater drilling work.

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Effect of carboxymethylcellulose on the rheological and filtration properties of bentonite clay samples determined by experimental planning and statistical analysis

Cerâmica ◽

10.1590/0366-69132018643702332 ◽

2018 ◽

Vol 64 (370) ◽

pp. 254-265 ◽

Cited By ~ 1

Author(s):

B. M. A. Brito ◽

P. M. Bastos ◽

A. J. A. Gama ◽

J. M. Cartaxo ◽

G. A. Neves ◽

...

Keyword(s):

Molecular Weight ◽

Statistical Analysis ◽

Rheological Properties ◽

Apparent Viscosity ◽

Bentonite Clay ◽

Plastic Viscosity ◽

Drilling Fluids ◽

Experimental Planning ◽

Water Based ◽

Filtration Properties

Abstract Over the past few years, considerable research has been conducted using the techniques of mixture delineation and statistical modeling. Through this methodology, applications in various technological fields have been found/optimized, especially in clay technology, leading to greater efficiency and reliability. This work studied the influence of carboxymethylcellulose on the rheological and filtration properties of bentonite dispersions to be applied in water-based drilling fluids using experimental planning and statistical analysis for clay mixtures. The dispersions were prepared according to Petrobras standard EP-1EP-00011-A, which deals with the testing of water-based drilling fluid viscosifiers for oil prospecting. The clay mixtures were transformed into sodic compounds, and carboxymethylcellulose additives of high and low molar mass were added, in order to improve their rheology and filtrate volume. Experimental planning and statistical analysis were used to verify the effect. The regression models were calculated for the relation between the compositions and the following rheological properties: apparent viscosity, plastic viscosity, and filtrate volume. The significance and validity of the models were confirmed. The results showed that the 3D response surfaces of the compositions with high molecular weight carboxymethylcellulose added were the ones that most contributed to the rise in apparent viscosity and plastic viscosity, and that those with low molecular weight were the ones that most helped in the reduction of the filtrate volume. Another important observation is that the experimental planning and statistical analysis can be used as an important auxiliary tool to optimize the rheological properties and filtrate volume of bentonite clay dispersions for use in drilling fluids when carboxymethylcellulose is added.

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Improving the rheological and fluid loss properties of the water-based mud using wheat flour

Multidiszciplináris Tudományok ◽

10.35925/j.multi.2021.1.15 ◽

2021 ◽

Vol 11 (1) ◽

pp. 137-145

Author(s):

Hani Ali Al Khalaf ◽

Zeeshan Ahmad ◽

Gabriella Kovácsné Federer

Keyword(s):

Yield Point ◽

Wheat Flour ◽

Apparent Viscosity ◽

Loss Rate ◽

Drilling Fluid ◽

Filter Press ◽

Fluid Loss ◽

Drilling Fluids ◽

Water Based ◽

Filtration Properties

This study aims to evaluate the effect of wheat flour as a natural and environmentally friendly material on the properties of water-based mud. Recently, many experiments have been conducted with various additives to improve the properties of drilling fluids. The effect of using wheat flour as a new additive to drilling fluid was studied to improve rheological and filtration properties. In the laboratory several samples of water-based mud were prepared, different concentrations of wheat flour from 1 wt% to 7 wt% were added to the mud and tested by using a Fann 35 viscometer, 140 Fann Mud balance, and an API LT-LP filter press. The results showed that adding 7 wt% of wheat flour was the optimal concentration. It was found that the apparent viscosity and yield point increased by 50% and 35%, respectively, when 7 wt% of wheat flour was added to the water-based drilling fluid. Likewise, the fluid loss rate was reduced by 25% when using the same concentration of wheat flour.

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An Experimental Investigation of Temperature and Aging Effects on Bentonite and Sepiolite Drilling Fluids

10.20944/preprints201807.0255.v1 ◽

2018 ◽

Author(s):

Tariq Ahmed ◽

Nura Makwashi

Keyword(s):

Rheological Properties ◽

Yield Point ◽

Xanthan Gum ◽

Ageing Time ◽

Drilling Fluid ◽

Gel Strength ◽

Plastic Viscosity ◽

Drilling Fluids ◽

Aging Effects ◽

Water Based

The selection and control of a suitable drilling fluid is necessary to successfully drill an oil and gas well. The rheological properties of drilling fluids vary with changes in conditions such as time and temperature. Slight changes in these conditions can cause unpredictable and significant changes in the mud’s properties. This makes it necessary to study the rheology of drilling fluids and how it is affected by these changes. At the rig sites, tests are carried out by the mud engineers to ensure that the properties of the drilling fluids are within the required limits. Similar tests were carried out at the laboratory in this work to determine the plastic viscosity, yield point, gel strength of mud samples at different conditions of ageing time, temperature and concentration of Xanthan gum (X.G) used as an additive. The Experiments carried out were grouped into three. The first was done with the aim to further explain how the Bentonite and Sepiolite water-based drilling fluids behaves after been aged for certain period. The second sets of experiments were conducted to investigate how the rheological properties of water-based Bentonite muds are affected by different concentration of xanthan gum added as an additive to improve the muds properties and the last sets of experiments were done to investigate the ageing effect on Bentonite mud treated with 250mg/L xanthan gum. Effects of temperature were also considered in these experiments with a 10℃ variation in the first group and 20℃ in the other two groups between readings from 20℃ to 60℃ . Results obtained indicated that Sepiolite water-based drilling fluid offers better plastic viscosity and yield point as compared to Bentonite water-based drilling fluids. It was also found that the viscosity and yield point of Sepiolite, Bentonite and treated Bentonite muds decreases with increase ageing time and temperature while the gel strength increases with ageing time but similarly decreases with increase in temperature. In the second group, results obtained indicated that plastic viscosity, yield point and gel strength increases as concentration of xanthan gum increases, all of which decreases with increase in temperature.

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Real-Time Prediction of Plastic Viscosity and Apparent Viscosity for Oil-Based Drilling Fluids Using a Committee Machine with Intelligent Systems

Arabian Journal for Science and Engineering ◽

10.1007/s13369-021-05748-8 ◽

2021 ◽

Author(s):

Mohamed Riad Youcefi ◽

Ahmed Hadjadj ◽

Abdelak Bentriou ◽

Farouk Said Boukredera

Keyword(s):

Real Time ◽

Apparent Viscosity ◽

Intelligent Systems ◽

Plastic Viscosity ◽

Drilling Fluids ◽

Committee Machine ◽

Time Prediction

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Comparison between the Effect of Local Katira Gum and Xanthan Gum on the Rheological Properties of Water-based Drilling Fluids

UHD Journal of Science and Technology ◽

10.21928/uhdjst.v4n2y2020.pp18-27 ◽

2020 ◽

Vol 4 (2) ◽

pp. 18

Author(s):

Bayan Qadir Sofy Hussein ◽

Khalid Mahmood Ismael Sharbazheri ◽

Nabil Adiel Tayeb Ubaid

Keyword(s):

Rheological Property ◽

Rheological Properties ◽

Yield Point ◽

Experimental Work ◽

Apparent Viscosity ◽

Xanthan Gum ◽

Drilling Fluid ◽

Drilling Fluids ◽

Drilling Mud ◽

Water Based

The rheological properties of drilling fluids have an important role in providing a stable wellbore and eliminating the borehole problems. Several materials including polymers (xanthan gum) can be used to improve these properties. In this study, the effect of the local Katira, as a new polymer, on the rheological properties of the drilling fluids prepared as the bentonite-water-based mud has been investigated in comparison with the conventional xanthan gum. Experimental work was done to study of rheological properties of several gums such as, local katira gum, and xanthan gum bentonite drilling mud. Different samples of drilling fluids are prepared adding the xanthan gum and local katira to the base drilling fluid at different concentrations using Hamilton Beach mixer. The prepared samples are passed through rheological property tests including the apparent viscosity, plastic viscosity, and yield point (YP) under different temperature conditions. The obtained results show that the viscosity is increased from 5 to 8.5 cp and YP is increased from 18.5 to 30.5 lb/100 ft2, with increasing the concentration of the xanthan gum from 0.1 to 0.4. However, the effect of the local katira in increasing the viscosity and YP is lower compared with the xanthan gum, which are ranged between 5–6 cp and 18.5–20.5 cp.

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Rheological Properties of Water-Based Drilling Fluids in Deep Offshore Conditions

Volume 8: Polar and Arctic Sciences and Technology; Petroleum Technology ◽

10.1115/omae2019-96719 ◽

2019 ◽

Author(s):

Qian Ding ◽

Baojiang Sun ◽

Zhiyuan Wang ◽

Yonghai Gao ◽

Yu Gao ◽

...

Keyword(s):

High Pressure ◽

High Temperature ◽

Low Temperature ◽

Rheological Properties ◽

Apparent Viscosity ◽

Drilling Fluid ◽

Plastic Viscosity ◽

Drilling Fluids ◽

Water Based ◽

Temperature And Pressure

Abstract In deep-water drilling, the drilling fluid is affected by the alternating temperature field derived from the low temperature of the seawater and the high temperature of the formation. The complicated wellbore temperature and pressure environments make the prediction of rheological properties of the drilling fluid difficult. In this study, the rheological properties of water-based drilling fluid in full temperature and pressure range of deep-water conditions were tested from 2 to 150 °C (35.6 to 302 °F) and 0.1 to 70 MPa (14.5 to 10000psi). The experiment was carried out by the OFI130-77 high temperature and high pressure rheometer. The experimental data were processed by multiple regression analysis method, and the mathematical model for predicting the apparent viscosity, plastic viscosity and yield point of water-based drilling fluid under high temperature and high pressure conditions was established. The experimental results show that when the temperature is lower than 65 °C (149 °F), the apparent viscosity and plastic viscosity of the water-based drilling fluid decrease significantly with increasing temperature. When the temperature is higher than 65 °C (149 °F), the apparent viscosity and plastic viscosity decrease slowly. Under low temperature conditions, the effect of pressure on the apparent viscosity and plastic viscosity of water-based drilling fluids is relatively significant. The calculated values of the prediction model have a good agreement with the experimental measurements. Compared with the traditional model, this prediction model has a significant improvement in the prediction accuracy in the low temperature section, which can provide a calculation basis for on-site application of deepwater drilling fluid.

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Nanoparticles Performance as Fluid Loss Additives in Water Based Drilling Fluids

Materials Science Forum ◽

10.4028/www.scientific.net/msf.864.189 ◽

2016 ◽

Vol 864 ◽

pp. 189-193 ◽

Cited By ~ 7

Author(s):

Abdul Razak Ismail ◽

Wan Rosli Wan Sulaiman ◽

Mohd Zaidi Jaafar ◽

Issham Ismail ◽

Elisabet Sabu Hera

Keyword(s):

Yield Point ◽

Xanthan Gum ◽

Drilling Fluid ◽

High Surface ◽

Volume Ratio ◽

Gel Strength ◽

Plastic Viscosity ◽

Fluid Loss ◽

Drilling Fluids ◽

Water Based

Nanoparticles are used to study the rheological characteristics of drilling fluids. Nanoparticles have high surface to volume ratio, therefore only small quantity is required to blend in the drilling fluid. This research evaluates the performance of nanosilica and multi walled carbon nanotubes (MWCNT) as fluid loss additives in water based drilling fluid with various nanoparticles concentration and temperature. The results show that plastic viscosity, yield point and gel strength of drilling fluid increases as the concentration of nanoparticles increased. Drilling fluid with nanosilica gives the highest filtrate loss of 12 ml and mudcake thickness of 10 inch at 1 g concentration at 300°F. However, drilling fluid with MWCNT shows a decreasing trend in fluid loss and mudcake thickness. The results also show that xanthan gum containing 1 g of MWCNT gives 4.9 ml fluid loss and mudcake thickness of 4 inch at 200°F. After aging, plastic viscosity, yield point and gel strength of mud containing nanoparticles decrease significantly especially for 1 g of nanosilica and 0.01 g MWCNT. Fluid loss and mudcake thickness increased when the mud is exposed to temperature above 250°F. The results showed that xanthan gum with MWCNT gives a better rheological performance.

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