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Article

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

by
Hany Gamal
,
Salaheldin Elkatatny
*,
Salem Basfar
and
Abdulaziz Al-Majed
Petroleum Department, King Fahd University of Petroleum & Minerals Box 5049, Dhahran 31261, Saudi Arabia
*
Author to whom correspondence should be addressed.
Sustainability 2019, 11(23), 6714; https://doi.org/10.3390/su11236714
Submission received: 5 November 2019 / Revised: 19 November 2019 / Accepted: 25 November 2019 / Published: 27 November 2019
(This article belongs to the Special Issue Drilling Technologies and Process Safety)
Browse Figures
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Abstract

:
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.

1. Introduction

The drilling fluids are critical in the oil and gas drilling operations. To reach the target formations in the well, the drilling fluid program should be designed carefully to safely drill the well with economical wise. Drilling fluids cost is considered to share a portion of around 25–40% of the total drilling operations cost [1]. Some problems that occur during the drilling operations such as mud losses will add more cost to the total drilling cost. Several factors affect the ratio of the drilling fluid cost to the total drilling cost, such as well location, drilled formation type, and other technical problems that might be encountered during the drilling operations [2,3]. The drilling fluids can be classified according to their base such as water-based, oil-based, gas-based, or synthetic-based, and all types are used in variable situations and with different additives [4]. Among these types, the water-based mud is the most commonly used drilling fluid [5]. The drilling mud is designed based on several factors and it should primarily be designed to control the formation pressure and to be environmentally friendly [4]. The mud design must consider the formation temperature, losses zones, and shale induced problems. The drilling fluids should provide the essential functions, including carrying cuttings out of the hole [hole cleaning], cooling and lubricating the drill string, providing wellbore stability, and should avoid damaging the formation. Moreover, the drilling fluids transfer the hydraulic power from the surface to downhole motors.

1.1. Bentonite in Drilling Fluids

Bentonite is a montmorillonite clay which is used with the drilling fluids to provide the required rheology [6,7,8,9]. Bentonite mainly used with water-based mud (WBM) to provide significant functions such as increasing the viscosity and filtration control [10]. Bentonite interacts chemically with the water and swells as it absorbs the water as a result. Bentonite as clays are naturally absorbent, and when the bentonite is exposed to water, bentonite attracts the positively charged surfaces in water to its negative face by electrostatic attraction forces [11]. This phenomenon enables the bentonite to absorb seven to 10 times its weight and swell up to 18 times its original volume [12]. Bentonite reacts chemically with several organic materials and forms compounds that are mainly used as gelling agents [13]. The mud gel strength is important for carrying the drilled cuttings in case no mud circulated.
Sodium bentonite is used in the drilling mud, is highly dispersive, and has a high swelling capability. Calcium bentonite is another type of bentonite, but it is not appropriate to be used as drilling fluid additive since it has the small swelling capability and it affects the mud rheology badly [10].
The raw bentonite is extracted and processed through many purification operations to be properly used with the drilling fluids. Mechanical and chemical processes are conducted for the raw bentonite such as sieving or adding chemicals to separate the pure bentonite from the impurities. The good quality of bentonite affects the mud rheological properties as it provides the essential viscosity and filtration loss [14,15,16].

1.2. Effect of Bentonite on Mud Rheology

Mud rheology is a very important property for the drilling fluids, which should be stable under various conditions while drilling to avoid any problems in the drilling operations. Mud rheological properties in terms of plastic viscosity, gel strength, etc. are tested frequently while drilling. Such properties are measured on a continuous basis during the drilling operations and should be adjusted by adding additives or dilution to meet the mud program design. Bentonite is one of the mud additives and its concentration should be evaluated as it affects the mud rheological properties [17]. The downhole pressure and temperature conditions affect the mud rheological properties. Therefore, flat-rheology fluid is designed to overcome the high-pressure, high-temperature HPHT drilling conditions. The rheology modifiers additives should provide a good profile for the HPHT applications [18].
Recently, research trends are directed to produce low solid content drilling fluids which require replacing some amount of bentonite by another nanoparticle for the drilling mud composition [19,20]. That low solid content fluid has several advantages, such as increasing the drilling rate of penetration, forming a thin filter cake layer, decreasing the friction losses, shale inhibition, and improving the rheological and filtration properties [21]. However, one of the main disadvantages of the low solid drilling fluid is the low carrying capacity of the drilled cuttings by the drilling mud [11]. Therefore, many kinds of research have been performed to improve the mud carrying capacity for the drilled cuttings by using additives to modify the mud rheological properties. Such additives include graphene oxide [22] and CuO and ZnO [23]. In addition, another work was conducted to modify the mud rheology using synthetic polymers such as terpolymer [24], amphoteric polymer [25], and copolymer [26]. The nanotechnology was also applied for the mud rheology modification [27,28,29,30].
Song et al. [8,9] studied the effect of using a small amount of cellulose nanoparticles to replace bentonite amount to modify the drilling fluid rheology. The study showed that the new formulation modified the mud rheological properties. The use of the cellulose nanoparticles formed a more negatively-charged surface on bentonite particles, increased the solution stability, and provided low fluid viscosity [31].
Ahmad et al. [19] studied the bentonite-polymer dispersions effect on the mud rheology and filtration properties. The study showed that bentonite-polymer dispersions greatly improved the rheological properties of the drilling fluid which indicates the ability of the bentonite-polymer to enhance the drilling fluid performance.
Li et al. [11] studied adding the chitin nanocrystals that are isolated from speckled swimming crab shell waste to the bentonite water-based mud as a rheology modifier. The results showed an improvement in the mud rheological and filtration properties. Saboori et al. [20] incorporated copper oxide/polyacrylamide nanocomposite into the bentonite water-based mud. The nanocomposite additive found to be more effective for filtration and mud rheology when it is added to water-based mud. The high-temperature affects the bentonite particles dispersions. The bottom hole high temperatures lead to bentonite aggregation, which could be prevented by adding several additives such as synthetic polymers, polysaccharides, cellulose, or starch as thinners [32].
Kanna et al. [33] studied the effect of bentonite and other mud additives on the mud optimum design in terms of mud rheology, pH value, and filtration properties. Huang et al. [34] showed that API Bentonite slurries displayed unusual rheology at low pH. The drilling fluid yield stress and viscosity had low values at low pH, and maximum yield stress and viscosity was found to be at pH 9. Akinade et al. [35] showed that the bentonite clay needed further improvements to be used in the drilling fluids to provide an optimum mud rheological and filtration properties as API standards. Kuma et al. [36] provided a study for the bentonite-based mud for properties improvement. The study tested adding carboxymethyl cellulose, sodium salt, partially hydrolyzed polyacrylamide (PHPA) polymer, and polyacrylamide, and the results showed an improvement in the mud rheological and filtration properties.
In addition, different polymers have been used in other filed applications such as polymer flooding for heavy oil reservoirs to increase the oil recovery [37,38]. The polymer flooding showed an economic profit performance than the steam-assisted gravity drainage system for heavy oil reservoirs [39].

1.3. Effect of Bentonite-Based Mud on Drilling Performance

From actual field data, it was found that bentonite-based mud had a bad effect on the penetration rate performance, and so it was recommended to reduce the bentonite amount as much as possible or to use another alternative than bentonite [40]. In the study, all the other factors that can affect the ROP as the hole size, weight on bit (WOB), rotation speed (RPM), bit type, drilled formation, bit hydraulics, and the mud type are similar to eliminate their effect. The study results showed that there is a direct relation between ROP and the mud viscosity, as ROP increased by 58% for adjusted mud rheological properties.
It is common in the Middle East to drill the surface hole sections with a spud mud composed of pre-hydrated bentonite. The shallow formations are soft and it is supposed to have losses during mud circulation. From practical, it is recommended to add thinner for the mud formula in case of the bentonite content 35–50 lb/bbl to control the mud viscosity. Due to the environmental constraints, using the inverted emulsion muds to drill the surface sections is not allowed. Bentonite-based spud mud is considered as an alternative to drill the surface sections. However, it is reported in the daily drilling data that the ROP decrease when using the bentonite-based mud when compared with emulsion mud, as shown in Figure 1. The real field drilling data showed that using emulsion mud system showed better ROP performance than using the high bentonite mud systems.
From the literature review, it is clear that bentonite affects the mud rheological and filtration properties, and the mud rheology design is critical for the drilling operation. In addition, the bentonite-based mud rheology affects the ROP, so it will have an impact on the well drilling cost. The work that has been discussed above mostly studied the additives used for the bentonite-based mud rheology modifier. Li et al. [11] focused on the pH effect for the bentonite water-based mud containing chitin nanocrystals as a mud modifier. They showed that the improvement in the mud rheology was found when the pH changed from neutral to acidic, and that might cause tubular corrosion. The previous discussion indicates that the effect of pH control on the bentonite water-based mud did not study very well in the literature.
In this study, the effect of changing the pH of water-based mud based on bentonite on the mud rheology and filtration properties will be extensively studied. Figure 2 illustrates a sketch that shows the change in the mud properties with the change of the pH vale. A recommendation of the optimum range for pH for this fluid type will be provided based on the obtained results. Sustain the rheological properties of the drilling fluid while drilling is very important which will help the driller to drill the hole faster and reduce the total cost of the drilling operation. In addition, optimizing the rheological properties will minimize or eliminate the fluid loss to any water bearing formation to protect the environment.
The used materials and the experimental procedure will be explained in Section 2. Results and discussion will be explained in details in Section 3. Finally, the summary and the conclusion will be explained in Section 4.

2. Materials and Experimental Procedure

2.1. Materials

The water-based drilling fluid based on bentonite (WBDFBOB) was mixed. Table 1 shows the composition of the WBDFBOB used in this study. The mud composed of water that represents the base fluid, bentonite as viscosifier, caustic soda to control the water activity, lignosulphonate for bentonite de-flocculation [41], and starch was used for fluid losses control. The formula used represents the base case for the study and other scenarios of changing only the pH for the formula were performed. Changing the pH was performed by increasing the amount of sodium hydroxide [NaOH] of the mud to reach the desired pH value.

2.2. Experimental Program

The water-based drilling fluid based on bentonite mud formulation in Table 1 was used to prepare the mud samples as follows:
  • Different samples of bentonite-based mud were mixed for different pH values [8,9,10,11,12].
  • Density was measured at ambient conditions for each sample.
  • Measurements for the rheological properties such as plastic viscosity (PV), yield point (YP), and gel strength [10-seconds, 10-minutes, 30-minutes readings] were obtained using the mud rheometer at a temperature of 120 °F and atmospheric pressure.
  • Filtration test was performed. The test was performed using the high-pressure, high-temperature filter cell under 300 psi differential pressure and 200 °F, and using a 25-micron ceramic disk. The test extended for 40 minutes until no flow out.
  • The filtrated volume and filter cake thickness was measured for each mud sample.
The drilling fluid pH was measured using the pH meter with an accuracy of ±0.05 while the mud density was measured using the mud balance with an accuracy of ±0.1. The rheological properties were obtained using the Fan VG 35 with an accuracy of ±0.5.

3. Results and Discussion

3.1. Mud Density

After mixing and preparing the bentonite-based mud with different pH values, the mud density was measured at ambient conditions. Figure 3 shows that there was no change in the fluid density as it remained constant at 8.8 ppg as the pH increased from 9 to 12.

3.2. Shear-Stress Shear-Rate Behavior

The shear-stress shear-rate behavior of the WBDFBOB for different pH at 120 °F was performed. The results, as shown in Figure 4, showed that increasing the pH for the samples resulted in decreasing the plastic viscosity, and Figure 4 indicated that from the shear-stress shear-rate curves. The curves show a similar increasing profile for the shear-stress shear-rate for all scenarios. The effect of pH on the mud rheological properties supposed to be because of a result of the change in the nanostructured of bentonite surfaces [11].

3.3. Rheological Properties

The values of the yield point (YP) represent a key control role in the efficiency of hole cleaning. Drilling mud with a greater value of YP is desired for the hole cleaning operations as it has a high level of carrying capacity for the mud solid particles and the drilled cuttings [35]. The plastic viscosity and YP for the bentonite-based WBM were measured over the pH range for this study. Figure 5 shows the changes in the plastic viscosity and YP for different the mud samples of WBDFBOB with different pH values. It is clear that increasing the pH from 8 to 12 resulted in decreasing the plastic viscosity from 62.4 to 29.3 cP, and also decreasing the YP from 85.7 to 15.8 lb/100 ft2. Increasing the pH from 8 to 12 resulted in decreeing the PV by 53% and the YP also decreased significantly by 82%.
Applying the Herschel-Bulkley flow model to determine the low-shear yield point (LSYP) [42], Equation (1).
LSYP = 3 R 3 − R 6
where R3 is the rheometer reading at 3 rpm and R6 is the rheometer reading at 6 rpm.
It is clear for Figure 5 that the value of LSYP was dramatically decreased by increasing the pH, where the LSYP was decreased from 80 lb/100 ft2 to 1.4 lb/100 ft2 as the pH increased from 8 to 12.
The obtained results confirmed the significant effect of the pH on the mud rheological and filtration properties. The reason for that is the change in mud rheology revealed that the nanostructure changes for the plates and particle surfaces of the drilling fluid based on the new value of the pH. In addition, the increase of pH values will prevent the dispersion of the bentonite particles, and as a result, the particles will not help in building the fluid viscosity. Furthermore, that will reduce the ability of the fluid to carry the drilled cuttings and that is appeared clearly by the lower YP values at higher pH.
The yield point to plastic viscosity YP/PV ratio for the mud is very important, as it is an indicator of the drilling operation conditions [1]. Turbulent flow is preferable in high-angle wells for hole cleaning. However, to ensure a mud gel strength is less important, as the carrying capacity does not affect by the mud rheology. In case turbulent flow cannot be maintained, the YP/PV ratio should be kept as high as possible. Also, if the hole gauging cannot be maintained and the borehole diameter enlarges, then a high YP/PV ratio is appropriate for the mud system. In laminar flow, the carrying capacity is affected by mud rheological properties. Therefore, when YP to plastic viscosity [YP/ PV] increases, the carrying capacity of the mud increases [1].
Figure 6 shows the changes in the YP/PV ratio over a wide range of pH for the bentonite-based mud. The highest value of YP/PV is 1.4 for pH of 8 and the ratio was 1.0 for pH values of [9,10] and it decreased to 0.5 for pH of 11 and 12. The results for YP/PV ratios show that for increasing pH values, there is a decreasing in the ratio of YP/PV by 64%.
The gel strength of drilling fluid represents the capability of the mud to keep the drilled cuttings in suspension in case of the circulation stopped [43]. The lab measurements for the mud gel strength are performed in a static condition after 10 sec, 10 minutes, and 30 minutes to evaluate the strength of the mud gelation with time for no circulation case. Figure 7 represents the gel strength measurements of high WBDFBOB for different pH values. Increasing the pH values significantly decreased the gel strength values. Therefore, pH has a key role in the mud gel strength. The 10-seconds gel strength values decreased from 10 to 3 lb/100 ft2 by increasing the pH from 8 to 12. The WBDFBOB gel strength values for 10-minutes readings showed a decreasing behavior from 30 to 3 lb/100 ft2. The readings for the 30-minutes gel strength decreased from 57 to 3 lb/100 ft2. The flat rheology for the mud is desired, as the fluid gel strength values should be constant with time with no increase [44]. The measurements of the WBDFBOB at a pH of 12 showed that flat rheology. However, the readings for the gel strength showed a slightly small increase for the samples of pH [9,10,11].

3.4. Filtration Properties

The HPHT filtration test results are plotted in Figure 8, which shows that the lower the pH for HBWBDF, the lower the filtrate volume, and vice versa. The bentonite-based mud sample that has 9.0 pH represents the lower filtrate volume 9.5 cm3, and increasing the pH resulted in increasing the filtrated volume up to 12.6 cm3 for the WBDFBOB sample of 12 pH.
The filter cake thickness also increased by increasing the pH. Figure 9 shows that for the mud sample with a pH of 9, the filter cake thickness was 2 mm. While increasing the pH, it was found that the filter cake thickness increased to 3.6 mm for WBDFBOB sample of 12 pH. Figure 10 shows the pictures for the filter cake formed for each filter press test for different pH samples of the HBWBDF.

3.5. Recommendation

In this study, the use of the WBDFBOB within pH in the range of 9 and 10 provided the best parameters for filtration and mud rheology comparing to the higher pH values [11,12], which could help for safe drilling operations. For the recommended pH [9,10] values, the YP/PV ratio is 1.0, the fluid has a good flat profile where gel strength readings are very close, and the filtration results presented the lowest filtrated volume (from 9.5 to 11 cm3) and filter cake thickness (from 2 to 2.9 mm).

4. Summary and Conclusions

The effect of the pH change on the water-based drilling fluid based on bentonite was experimentally investigated. Based on the obtained results, the following conclusions can be summarized:
  • The pH significantly affects the mud rheology for the WBDFBOB, and there was no change in the fluid density as it remained constant at 8.8 ppg with changing the pH from 9 to 12.
  • The shear-stress vs shear-rate curve changed with changing the pH. Increasing the pH resulted in decreasing the shear-stress over the same shear-rate.
  • It is clear that increasing the pH from 8 to 12 resulted in decreasing the plastic viscosity by 53% and the YP by 82%, respectively. The highest value of YP/PV was 1.4 for the mud sample with a pH of 8. The YP/PV ratios were decreased by 64% as the pH increased from 8 to 12.
  • Increasing the pH from 8 to 12 had a significant effect on the gel strength where the 10-sec gel strength was decreased by 77%, the 10-min gel strength was decreased by 90%, and the 30 min gel strength was decreased by 95%.
  • Changing the pH for the bentonite-based samples had an impact on the filtration properties for the mud. Increasing the pH from 9 to 10 resulted in increasing the filtrated volume by 33% and also increasing the filter cake thickness by 79%.
It is clear that optimizing the pH in the range of 9 to 10 has a significant effect on the rheological properties and the mud filtration which will enhance the performance of the drilling operation. Reducing the PV will increase the rate of penetration and will reduce the pump pressure required to circulate the fluid up to the surface. In addition, reducing the filtrate volume will eliminate the formation damage and will yield a thin filter cake which helps in eliminating the pipe sticking, and as a result, reducing the nonproductive time.
Unit Conversion: 1 ppg = 0.0083 kg/m3, 1 °F = 255.928 °K, 1 lb/ft2 = 4.788 E5 N/mm2, cP = 10−3 Pa.s, 1 ft = 0.3028 m.

Author Contributions

Conceptualization, S.B., and H.G.; methodology, S.B., A.A.-M.; validation, S.E., H.G.; formal analysis, S.B., H.G.; investigation, A.A.-M., S.E.; resources, S.E.; data curation, S.B.; writing—original draft preparation, H.G.; writing—review and editing, S.E., A.A.-M.; visualization, A.A.-M., S.E.; supervision, S.E.

Funding

This research received no external funding.

Acknowledgments

The authors wish to acknowledge King Fahd University of Petroleum and Minerals (KFUPM) for utilizing the various facilities in carrying out this research.

Conflicts of Interest

The author declares no conflict of interest.

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Figure 1. Drilling ROP comparison between bentonite-based and emulsion muds (Field Data).
Figure 1. Drilling ROP comparison between bentonite-based and emulsion muds (Field Data).
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Figure 2. Change in the mud properties with changing the pH.
Figure 2. Change in the mud properties with changing the pH.
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Figure 3. Density of bentonite-based mud at ambient condition for different pH.
Figure 3. Density of bentonite-based mud at ambient condition for different pH.
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Figure 4. Shear-stress shear-rate behavior of WBDFBOB at 120 °F for different pH scenarios.
Figure 4. Shear-stress shear-rate behavior of WBDFBOB at 120 °F for different pH scenarios.
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Figure 5. Change of PV, YP, and LSYP of WBDFBOB for different pH scenarios at 120 °F.
Figure 5. Change of PV, YP, and LSYP of WBDFBOB for different pH scenarios at 120 °F.
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Figure 6. Change of YP/PV ratio of WBDFBOB for different pH.
Figure 6. Change of YP/PV ratio of WBDFBOB for different pH.
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Figure 7. Gel strength measurements of WBDFBOB for different pH.
Figure 7. Gel strength measurements of WBDFBOB for different pH.
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Figure 8. Filtrate volume for different pH samples of WBDFBOB after 30 minutes.
Figure 8. Filtrate volume for different pH samples of WBDFBOB after 30 minutes.
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Figure 9. Filter cake thickness for different pH samples of HBWBDF.
Figure 9. Filter cake thickness for different pH samples of HBWBDF.
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Figure 10. Filter cake for different pH samples of HBWBDF.
Figure 10. Filter cake for different pH samples of HBWBDF.
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Table
Table 1. Composition of HBWBDF.
Table 1. Composition of HBWBDF.
ItemAmount, gFunction
Water340Base fluid
Bentonite40Viscosifier
Caustic Soda0.5Water Activity
Lignosulphonate3Dispersant
Starch3Fluid loss control

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Gamal, H.; Elkatatny, S.; Basfar, S.; Al-Majed, A. Effect of pH on Rheological and Filtration Properties of Water-Based Drilling Fluid Based on Bentonite. Sustainability 2019, 11, 6714. https://doi.org/10.3390/su11236714

AMA Style

Gamal H, Elkatatny S, Basfar S, Al-Majed A. Effect of pH on Rheological and Filtration Properties of Water-Based Drilling Fluid Based on Bentonite. Sustainability. 2019; 11(23):6714. https://doi.org/10.3390/su11236714

Chicago/Turabian Style

Gamal, Hany, Salaheldin Elkatatny, Salem Basfar, and Abdulaziz Al-Majed. 2019. "Effect of pH on Rheological and Filtration Properties of Water-Based Drilling Fluid Based on Bentonite" Sustainability 11, no. 23: 6714. https://doi.org/10.3390/su11236714

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