scholarly journals Improvement of Locally Available Raw Bentonite for Use as Drilling Mud

2017 ◽  
Vol 11 (1) ◽  
pp. 274-284
Author(s):  
Kaffayatullah Khan ◽  
Shaukat Ali Khan ◽  
Muhammad Umair Saleem ◽  
Muhammad Ashraf
Keyword(s):  
Rheological Properties ◽  
Yield Point ◽  
Carboxymethyl Cellulose ◽  
Drilling Fluid ◽  
Gel Strength ◽  
Plastic Viscosity ◽  
Drilling Process ◽  
Drilling Operation ◽  
Bentonite Clays ◽  
Filtrate Loss

Background: Bentonite clays are widely used in a drilling operation and play a vital role as a drilling fluid. Bentonite clay mud performs several functions during the drilling operation and facilitates the drilling process. Objective: In this study, the locally available raw bentonite clays were investigated to evaluate its potential use as a mud for borehole drilling operation after its improvement with the additives. Method: Rheological properties such as plastic viscosity, yield point and gel strength were evaluated by using a viscometer and filtrate loss test was performed by using filter press on both locally available raw bentonite clays and the commercial bentonite named as Mill gel. Results: From the test results obtained for the up gradation of clays with the different beneficiating materials, the drastic increase in the plastic viscosity, yield point and gel strength has been observed. It shows that Xanthum gum produced better results for the improvement of rheological properties of such clays. Carboxymethyl cellulose and starch were used as additives and it has been observed that carboxymethyl cellulose has improved both viscosity and filtrate loss control, whereas starch muds have the best filtration control properties. Conclusion: Improved bentonite clays have rheological and filtration characteristics that have satisfied American Petroleum Institute specification at optimum conditions of clay. It was concluded that improved clays are the suitable material for the drilling operations and suitable to substitute commercial bentonite.

scholarly journals Effect of pH on Rheological and Filtration Properties of Water-Based Drilling Fluid Based on Bentonite

2019 ◽  
Vol 11 (23) ◽  
pp. 6714 ◽  
Author(s):  
Hany Gamal ◽  
Salaheldin Elkatatny ◽  
Salem Basfar ◽  
Abdulaziz Al-Majed
Keyword(s):  
Rheological Properties ◽  
Yield Point ◽  
Filter Cake ◽  
Drilling Fluid ◽  
Gel Strength ◽  
Plastic Viscosity ◽  
Effect Of Ph ◽  
Drilling Operation ◽  
Water Based ◽  
Filtration Properties

The design of drilling fluids is very important for the drilling operation success. The rheological properties play a key role in the performance of the drilling fluid. Therefore, studying the mud rheological properties of the water-based drilling fluid based on bentonite is essential. The main objectives of this study are to address the effect of pH changes on the rheological and filtration properties of the water-based drilling fluid based on bentonite and to provide a recommended pH range for this drilling fluid for a safe and high-performance drilling operation. Different samples of the water-based drilling fluid based on bentonite with different pH values were prepared, and the rheological properties such as plastic viscosity, yield point, and gel strength were measured. After that, the filtration test was performed under 300 psi differential pressure and 200 °F. The pH for the water-based drilling fluid based on bentonite significantly affects the mud rheology. The shear stress and shear rate relation were varying with the change in the pH. Increasing the pH from 8 to 12 resulted in decreasing the plastic viscosity by 53% and the yield point by 82%, respectively. The ratio of yield point / plastic viscosity was 1.4 for pH of 8 while it decreased to 0.5 for a pH of 11 and 12. There was a significant decrease in the gel strength readings by increasing the pH. The filtrate volume and filter cake thickness increased by increasing pH. The filtration volume increased from 9.5 cm3 to 12.6 cm3 by increasing the pH from 9 to 12. The filter cake thickness was 2 mm at 9 pH, while it was increased to 3.6 mm for 12 pH. It is recommended from the results to keep the pH of water-based drilling fluid based on bentonite in the range of 9 to 10 as it provides the optimum mud rheological and filtration properties. The findings of this study illustrated that keeping the pH in the range of 9 to 10 will reduce the plastic viscosity that will help in increasing the rate of penetration and reducing the required pump pressure to circulate the mud to the surface which will help to sustain the drilling operation. In addition, reducing the filtrate volume will produce a thin filter cake which will help in avoiding the pipe sticking and protect the environment. In general, optimizing the pH of the water-based drilling fluid based on bentonite in the range of 9 to 10 will improve the drilling operation and minimize the total cost.

scholarly journals Studying the Effects of Different Polymers on Rheological Properties of Water Base Muds

2018 ◽  
Vol 24 (12) ◽  
pp. 12-25 ◽  
Author(s):  
Amel Habeeb Assi ◽  
Ramzi Riyadh Khazeem ◽  
Ahmed Salah Salem ◽  
Alaa Tahseen Ali
Keyword(s):  
Rheological Properties ◽  
Yield Point ◽  
Xanthan Gum ◽  
Drilling Fluid ◽  
Methyl Cellulose ◽  
Gel Strength ◽  
Plastic Viscosity ◽  
Filtration Loss ◽  
Different Types ◽  
Water Base

This research is focusing on finding more effective polymers that leads to enhance the rheological properties of Water Base Muds. The experiments are done for different types of mud for all substances which are Polyacrylamide, Xanthan gum, CMC (Carboxyl Methyl Cellulose). This study shows the effect of add polymer to red bentonite mud, effect of add polymer to Iraqi bentonite mud, the effect of add bentonite to polymer mud. The mud properties of Iraqi bentonite blank are enhanced after adding the polymers to the blank mix, CMC gives the highest value of plastic viscosity and Gel strength than others; X-anthan gives the highest value of yield point and gel strength than others. For the red bentonite mud, Polyacrylamide has the highest shear stress and yield point than the others polymers, but Xanthan has the highest effect on plastic viscosity than other polymers. All polymers reduce filtration loss. The polymer solution mud failed to suspend the barite so we cannot use it as drilling fluid even so this mud has good Rheological properties (PV and YP). The maximum amount of each polymer is founded for the studied clay types.                                                             

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

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.

scholarly journals Experimental analysis of drilling fluid prepared by mixing iron (III) oxide nanoparticles with a KCl–Glycol–PHPA polymer-based mud used in drilling operation

2020 ◽  
Vol 10 (8) ◽  
pp. 3389-3397 ◽  
Author(s):  
Nayem Ahmed ◽  
Md. Saiful Alam ◽  
M. A. Salam
Keyword(s):  
Filter Cake ◽  
Drilling Fluid ◽  
Gel Strength ◽  
Filter Press ◽  
Plastic Viscosity ◽  
Fluid Loss ◽  
Drilling Mud ◽  
Drilling Operation ◽  
Critical Issues ◽  
Mud Loss

Abstract Loss of drilling fluid commonly known as mud loss is considered as one of the critical issues during the drilling operation as it can cause severe formation damage. To minimize fluid loss, researchers introduced numerous additives but did not get the expected result. Recently, the use of nanoparticles (NPs) in drilling fluid gives a new hope to control the fluid loss. A basic KCl–Glycol–PHPA polymer-based mud is made, and six different concentrations of 0.1, 0.5, 1.0, 1.5, 2.0, 3.0 wt% iron (III) oxide or Hematite (Fe2O3) NPs are mixed with the basic mud. The experimental observations reveal that fluid loss of basic mud is 5.9 ml after 30 min and prepared nano-based drilling mud results in a less fluid loss at all concentrations. Nanoparticles with a concentration of 0.5 wt% result in a 5.1 ml fluid loss at the API LTLP filter press test. On the other hand, nanoparticles with a concentration of 3.0 wt% enhance the plastic viscosity, yield point, and 10 s gel strength by 15.0, 3.0, and 12.5%, respectively. The optimum concentration of hematite NPs is found to be 0.5 wt% which reduces the API LPLT filtrate volume and filter cake thickness by 13.6 and 40%, respectively, as well as an improvement of plastic viscosity by 10%.

scholarly journals The application of MWCNT to enhance the rheological behavior of drilling fluids at high temperature

2017 ◽  
Vol 12 (3) ◽  
Author(s):  
Abdul Razak Ismail ◽  
W. R. W Sulaiman ◽  
M. Z. Jaafar ◽  
A. Aftab ◽  
A. A. Razi ◽  
...  
Keyword(s):  
High Temperature ◽  
Rheological Properties ◽  
Rheological Behavior ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Gel Strength ◽  
Drilling Fluids ◽  
Deep Wells ◽  
Multi Walled Carbon Nanotube ◽  
Filtrate Loss

Drilling fluid is the key component to drill oil and gas wells. The rheological behavior of drilling fluid will be affected when drilling deep wells especially at high temperature and high pressure reservoir. This research was conducted to study the effect of the nanoparticles over the rheological properties of the drilling fluid when aging at high temperature condition. Several drilling fluids were prepared using synthetic based fluids (Sarapar and Saraline) to study the effect of multi-walled carbon nanotube (MWCNT) at different concentrations. The rheological properties of drilling fluid were analyzed after aging at 250 °F and 350 °F for 16 hours. The results revealed that the addition of MWCNT improved the 10-sec gel strength by 33% and filtrate loss volume was reduced to 10% after aging at 250°F in Saraline drilling fluid. Moreover, the plastic viscosity of Saraline and Sarapar drilling fluid after addition of MWCNT was enhanced by 6% and 27% at 350 °F. Filtrate loss volume of Sarapar drilling fluid was reduced by 19 % after aging at 250 °F for 16 hours. The overall results showed that the addition of MWCNT into the drilling fluid have slightly improved the rheological properties of drilling fluids under high temperature conditions.

scholarly journals Enhancing the Rheological Properties of Water-Based Drilling Fluid by Utilizing of Environmentally-Friendly Materials

2021 ◽  
Vol 11 (3) ◽  
pp. 66-81
Author(s):  
Amel Habeeb Assi ◽  
Ahmed Abdallah Haiawi
Keyword(s):  
Rheological Properties ◽  
Yield Point ◽  
Ph Value ◽  
Drilling Fluid ◽  
Environmentally Friendly ◽  
Plastic Viscosity ◽  
Drilling Fluids ◽  
Corn Cob ◽  
Chemical Additives ◽  
Main Components

Recently, many materials have shown that they can be used as alternatives to chemicals materials in order to be used to improve the properties of drilling fluids. Some of these materials are banana peels and corn cobs which both are considered environmentally- friendly materials. The results of the X-ray diffraction examination have proved that the main components of these materials are cellulose and hemicellulose, which contribute greatly to the increasing of the effectiveness of these two materials. Due to their distinct composition, these two materials have improved the rheological properties (plastic viscosity and yield point) and reduced the filtration of the drilling fluids to a large extent. The addition rates used for each of the two materials (banana peels and corn cob) are 1%, 2%, 3%, 4%, 5% and 6%. As regard to banana peels, the results have shown that there is a direct correlation between the addition ratios, the increase in the rheological properties (plastic viscosity and yield point), and the decrease in filtration The corn cob has shown the same results. Also, 0.01% increase in the pH value was observed when adding a corn cob, while adding banana peels showed the opposite, as adding them led to 0.02% decrease in the pH value. Among the other properties that have been studied is density, as it has been noticed that there is no significant effect of these two materials on the density of drilling fluid. Moreover, the performance of these two materials has been compared with the PAC polymer. This research suggests that the possibility of moving towards corn cob and dried banana peels as additives for biodegradable drilling fluid. Apart from being environmentally friendly, the choice of using them is considered economically more efficient than other chemical additives. By all accounts, the above materials are an increasingly rational choice for moving forward for an environmentally friendly oil industry.

scholarly journals Effect of High Temperature on Rheology and Electrical Stability of Saraline and Smooth Fluid 05 Mud

2019 ◽  
Vol 2 (1) ◽  
Author(s):  
Apriandi Rizkina Rangga Wastu ◽  
Muhammad Taufiq Fathaddin ◽  
Abdul Hamid
Keyword(s):  
High Temperature ◽  
Yield Point ◽  
Drilling Fluid ◽  
Gel Strength ◽  
Drilling Mud ◽  
Electrical Stability ◽  
Drilling Operation ◽  
Limit Value ◽  
A Value ◽  
Drilling Operations

<p><em>In drilling operations, drilling mud plays a very important role because it is irreplaceable functions. Drilling activities relate to problems caused by complex conditions in formation due to changes in temperature, pressure, and contamination from formation fluids. Using Oil Base Mud (OBM) mud systems in the form of Saraline and Smooth Fluid 05 is tested for drilling fluid performance and the results can be a reference for drilling operation. This research consist of two parts, the first: determining the drilling mud rheology value in the form of (Plastic Viscosity, Yield Point and Gel Strength) in each drilling mud of Saraline and Smooth fluid 05 mud using various high temperature parameters of 350<sup>o</sup>F, 300<sup>o</sup>F, and 270<sup>o</sup>F. The results of the mud rheology tests show at the higher the temperature, the values of rheology decreases. The second experiment is to determine the level of electrical stability in the mud which functions of oil-wet content in oil sludge (Saraline and Smooth fluid 05). The electrical stability value has a minimum limit value in OBM, which is 500 volts. In this experiment showed that the higher the temperature value, the electrical stability value in the mud will decrease, but in this study the value of electrical stability in Saraline mud and Smooth fluid 05 has a value above 500 volts, the composition OBM of Saraline and Smooth Fluid 05 sludge has very good oilwet content</em><em>.</em></p>

Nanoparticles Performance as Fluid Loss Additives in Water Based Drilling Fluids

2016 ◽  
Vol 864 ◽  
pp. 189-193 ◽  
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.

Enhancement lubricity properties of water-based mud with nanoparticles

2020 ◽  
pp. 70-74
Author(s):  
V.V. Guliyev ◽  
◽  
◽  
Keyword(s):  
Yield Point ◽  
Coefficient Of Friction ◽  
Drilling Fluid ◽  
Research Work ◽  
Shear Thinning ◽  
Rheological Parameters ◽  
Drilling Process ◽  
Drilling Mud ◽  
Pseudoplastic Fluid ◽  
Water Based

Currently, a great number of drilling fluids with different additives are used all over the world. Such additives are applied to control the properties of the drilling mud. The main purpose for controlling is to achieve more effective and safe drilling process. This research work aims to develop Water-Based Mud (WBM) with a Coefficient of Friction (CoF) as low as Oil-Based Mud (OBM) and better rheological properties. As it is known, produced CoF by WBM is higher than OBM, which means high friction between wellbore or casing and drill string. It was the reason for studying the effect of nanosilica on drilling fluid properties such as lubricity, rheological parameters and filtrate loss volume of drilling mud. The procedures were carried out following API RP 13B and API 13I standards. Five concentrations of nanosilica were selected to be tested. According to the results obtained, it was defined that adding nanosilica into the mud decreases CoF of basic WBM by 26 % and justifies nanosilica as a good lubricating agent for drilling fluid. The decreasing trend in coefficient of friction and plastic viscosity for nanosilica was obtained until the concentration of 0.1 %. This reduction is due to the shear thinning or pseudoplastic fluid behavior. After 0.1 %, an increase at PV value trend indicates that it does not follow shear thinning behavior and after reaching a certain amount of dissolved solids in the mud, it acts like normal drilling fluid. The yield point of the mud containing nanoparticles was higher than the basic one. Moreover, a growth in the concentration leads to an increase in yield point value. The improvement of this fluid system cleaning capacity via hydraulics modification and wellhole stability by filter cake endurance increase by adding nanosilica is shown as well. The average well construction data of “Neft Dashlary” field was used for the simulation studies conducted for the investigation of hydraulics parameters of reviewed fluids for all series of experiments. The test results were accepted reliable in case of at least 3 times repeatability.

scholarly journals Comparative Analysis of the Effect of Barite and Hematite on the Rheology of Water-Based Drilling Mud

2021 ◽  
Vol 1 (2) ◽  
Author(s):  
Osei H
Keyword(s):  
Rheological Properties ◽  
Drilling Fluid ◽  
Attrition Rate ◽  
Drilling Mud ◽  
Cleaning Efficiency ◽  
Drilling Operation ◽  
Water Based ◽  
Petroleum Resources ◽  
Drilling Muds ◽  
The Impact

High demand for oil and gas has led to exploration of more petroleum resources even at remote areas. The petroleum resources are found in deeper subsurface formations and drilling into such formations requires a well-designed drilling mud with suitable rheological properties in order to avoid or reduce associated drilling problems. This is because rheological properties of drilling muds have considerable effect on the drilling operation and cleaning of the wellbore. Mud engineers therefore use mud additives to influence the properties and functions of the drilling fluid to obtain the desired drilling mud properties especially rheological properties. This study investigated and compared the impact of barite and hematite as weighting agents for water-based drilling muds and their influence on the rheology. Water-based muds of different concentrations of weighting agents (5%, 10%, 15% and 20% of the total weight of the drilling mud) were prepared and their rheological properties determined at an ambient temperature of 24ᵒC to check their impact on drilling operation. The results found hematite to produce higher mud density, plastic viscosity, gel strength and yield point when compared to barite at the same weighting concentrations. The higher performance of the hematite-based muds might be attributed to it having higher specific gravity, better particle distribution and lower particle attrition rate and more importantly being free from contaminants. The water-based muds with hematite will therefore be more promising drilling muds with higher drilling and hole cleaning efficiency than those having barite.

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