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1
Yue, Qian Sheng, Qing Zhi Yang, Shu Jie Liu, Bao Sheng He, and You Lin Hu. "Rheological Properties of Water Based Drilling Fluid in Deep Water Drilling Conditions." Applied Mechanics and Materials 318 (May 2013): 507–12. http://dx.doi.org/10.4028/www.scientific.net/amm.318.507.
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The rheological property of the drilling fluid was one of the focus problems in deep-water drilling, which was widely concerned. In the article, the viscosity-temperature properties of commonly used water soluble polymeric solution, polymeric brine solution, bentonite slurry, polyacrylamide-potassium chloride drilling fluid with different densities and water-base drilling fluid systems commonly used for China offshore well drillings were studied. 4°C-to-20°C viscosity ratio and 4°C-to-20°C YP ratio were used to judge the thickening level of drilling fluids due to low temperature. The experimental results show that on the condition of without considering the influence of pressure on the rheological property of water-base drilling fluid, its viscosity and yield point raised obviously with the decrease of temperature, but the increase level is proximately the same, its 4°C-to-20°C apparent viscosity ratio is basically within the 1.50. Analysis indicates that the viscosity of water-base drilling fluid depends on the viscosity of dispersed media. The performance of water medium determines the viscosity-temperature property of the water-based drilling fluid. It is proposed that in deep water drillings, if a water-base drilling fluid is used, it is not necessary to emphasize the influence of deep water and low temperature on the flowability. On the condition of guaranteeing wellbore stability and borehole cleaning, it is more suitable for using the water-base drilling fluid with low viscosity and low gel strength for deep water well drillings.
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Yalman, Emine, Gabriella Federer-Kovacs, and Tolga Depci. "Development of Water-Based Drilling Fluid in Mitigation of Differential Sticking Tendency." Rudarsko-geološko-naftni zbornik 38, no. 2 (2022): 13–21. http://dx.doi.org/10.17794/rgn.2022.2.2.
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The objective of the study is to design a drilling fluid that prevents differential pressure pipe sticking tendency caused by drilling fluid with fly ash that is an industrial waste generated from the combustion of coal. To this end, drilling fluid samples were prepared with different particle sizes obtained through the sieving and grinding process and increasing concentrations of fly ash. Differential pipe sticking tests of the samples were performed by applying 3.447 MPa (500 psi) pressure and using a Fann Model 21150 Differential Sticking Tester in order to determine how the coefficient of sticking and torque reading varied with the fly ash. From the results, it was observed that the coefficient of sticking and torque reading of the water-based drilling fluids decreased up to a specific concentration as the concentration of fly ash increased. Furthermore, particle size analysis illustrated that the coefficient of sticking and torque of the drilling fluid differs depending on the particle size of fly ash introduced. The drilling fluid designed with ground fly ash demonstrated lower sticking coefficient and torque reading than that of drilling fluids formulated with raw and sieved fly ashes. The experimental study revealed that fly ash is a promising additive in the mitigation of differential sticking tendency caused by water-based drilling fluids.
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Belayneh, Mesfin, Bernt Aadnøy, and Simen Moe Strømø. "MoS2 Nanoparticle Effects on 80 °C Thermally Stable Water-Based Drilling Fluid." Materials 14, no. 23 (2021): 7195. http://dx.doi.org/10.3390/ma14237195.
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Bentonite-based drilling fluids are used for drilling, where inhibitive fluids are not required. The rheological and the density properties of the drilling fluids are highly affected by high temperature and pressure. Due to high temperature, the clay particles stick together, and the fluid system becomes more flocculated. Poorly designed drilling fluid may cause undesired operational issues such as poor hole cleaning, drill strings sticking, high torque and drag. In this study, the 80 °C thermally stable Herschel Bulkley’s and Bingham plastic yield stresses drilling fluids were formulated based on lignosulfonate-treated bentonite drilling fluid. Further, the impact of a MoS2 nanoparticle solution on the properties of the thermally stable base fluid was characterized. Results at room temperature and pressure showed that the blending of 0.26 wt.% MoS2 increased the lubricity of thermally stable base fluid by 27% and enhanced the thermal and electrical conductivities by 7.2% and 8.8%, respectively.
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Xie, Gang, Ming Yi Deng, Jun Lin Su, and Liang Chun Pu. "Study on Shale Gas Drilling Fluids Technology." Advanced Materials Research 868 (December 2013): 651–56. http://dx.doi.org/10.4028/www.scientific.net/amr.868.651.
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Via discussing the advantages and disadvantages of different types of oil-based drilling fluids, the main reason why oil-based drilling fluids are less used in our country is obtained that dont form a complete series of matching technology. The essence of wellbore instability caused by using water-based drilling fluids to drill shale is analyzed that the formation collapse pressure is greater than drilling fluids column pressure. The fundamental way of controlling borehole wall stability that use water-based drilling fluids to drill shale horizontal well was proposed that deeply researched the shale hydration mechanism, developed efficient blocking agent and inhibitors and established shale gas drilling fluid suppression system, which made water-based drilling fluids have excellent performance.
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Momeni, Ali, Seyyed Shahab Tabatabaee Moradi, and Seyyed Alireza Tabatabaei-Nejad. "A REVIEW ON GLYCEROL-BASED DRILLING FLUIDS AND GLYCERINE AS A DRILLING FLUID ADDITIVE." Rudarsko-geološko-naftni zbornik 39, no. 1 (2024): 87–99. http://dx.doi.org/10.17794/rgn.2024.1.8.
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A significant increase of energy demands all over the world and production decline from available oil and gas reservoirs have led the industry to invest in major offshore petroleum resources. However, drilling operations in offshore environments are usually restricted by environmental constraints. Therefore, recent studies are devoted to the development of environmentally compatible fluids with adequate technical properties. Glycerine is a non-toxic, lubricating, colorless, odorless substance with a higher density than water. Due to the properties of glycerine, it can be used as the base of drilling fluid to formulate synthetic-based fluids. This research aimed to review the studies on the applications of glycerine in the composition of drilling fluid. Based on the results, glycerine-based fluids can be considered as an environmentally compatible fluid with sufficient technical properties to replace other drilling fluids. However, there is a lack of experimental studies on the glycerine fluid properties for a reliable decision. For the application of glycerine fluids, an economic feasibility study is mandatory for both pure and crude glycerine. Also, the thermal stability of glycerine fluids is an important aspect, which should be covered in future research studies.
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Nekrasova, I. L., P. A. Khvoshchin, D. A. Kazakov, and O. V. Garshina. "Water-based drilling fluids utilization." Environmental Protection in Oil and Gas Complex, no. 4 (2022): 5–13. http://dx.doi.org/10.33285/2411-7013-2022-4(307)-5-13.
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Vamsi, Krishna Kudapa. "Experimental investigation of water based drilling mud by using graphene." i-manager's Journal on Material Science 10, no. 2 (2022): 9. http://dx.doi.org/10.26634/jms.10.2.19037.
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In the oil and gas industry, the need for a particular composition-based drilling mud is characterized by its rheological and fluid loss properties. Enhancing these properties will increase the efficiency of drilling fluid and, hence, the wellbore damage will be controlled. Recent advancements show that the application of nanoparticles in drilling fluids will enhance their efficiency. This research investigates the influence of adding graphene nanoparticles on the performance of water-based drilling fluids. The main objective of this experiment was to investigate the effect of nanoparticles on water-based drilling mud with different concentrations of nanoparticles added to the mud.
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Feneuil, Blandine, Bjørnar Lund, Inga Synnøve Nordhus, et al. "Flow Curves and Fluid Loss of Water-Based Drilling Fluids." Annual Transactions of the Nordic Rheology Society 33 (May 9, 2025): 103–16. https://doi.org/10.31265/atnrs.870.
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A drilling fluid must fulfill numerous functions during well drilling, ranging from particle transport, lubrication, to wall stabilization. In that aim, the composition is carefully chosen by the drilling engineer for each well section according to the required properties such as density, rheological properties, chemical stability, and fluid loss. In particular, fluid loss refers to the penetration of the liquid from the drilling fluid into the rock formation. It must be controlled and preferably avoided as it may reduce the permeability of the formation and change the fluid properties due to the depletion of the liquid. Fluids with low fluid loss can form an impermeable filter cake at the rock surface, i.e., a layer of accumulated particles on the wall of the well. As interest in CO2 storage has increased in the last decade, the need to design drilling fluids for CO2 well drilling has arisen. Lots of knowledge is inherited from oil & gas wells, and still, CO2 wells pose new challenges. These wells should not be optimized for production (receiving fluids from the formation into the well), but for injection (injecting CO2 from the well into the rock formation). Here, we present an experimental study aiming to optimize drilling fluids' rheological properties and fluid loss for CO2 wells. Flow curves are measured using a Couette cell in an Anton Paar rheometer. Fluid loss and filter cake formation are evaluated with a filter press. We investigate the effect of the fluid components on the flow curve, the fluid loss, and the filter cake mass.
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Shudryk, Oleksandr, Nataliia Shevchenko, Kseniya Rezvaya, Maryna Petruniak, and Viktor Bovkun. "FLOW ANALYSIS IN A ROLLER DRILL BIT DURING DRILLING USING WATER-BASED AND HYDROCARBON-BASED MUD." Bulletin of the National Technical University "KhPI". Series: Hydraulic machines and hydraulic units, no. 1 (November 29, 2024): 58–64. https://doi.org/10.20998/2411-3441.2024.1.08.
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Drilling is the main type of increase in hydrocarbon production. Bits of various types are used as a rock-destroying tool during drilling. When drilling any wells for oil and gas, drilling fluids are used as a working fluid. The flow of these types of liquids differs from the flow of water, which is an incompressible medium. The purpose of this work is to study the flow of the Newtonian fluid of water and two types of water-based drilling fluids, which is described by the power-law model of a non-Newtonian fluid and the hydrocarbon-based fluid of the Herschel-Bulkley type. In the work, the construction of the geometric model of the square bit was carried out, and the estimated unstructured grid of the liquid volume filling the internal area of the bit and the space behind the bit was constructed. Calculations of the three-dimensional flow of water, drilling fluids on water and hydrocarbon bases were carried out using the open platform OpenFOAM. It was found that during the flow of liquids described by non-Newtonian models, the kinematic viscosity of the liquid changes depending on the velocities and shear stresses. Another important factor in the use of non-Newtonian fluids when drilling wells is the reduction of hydraulic losses during their flow. This is achieved due to the presence of a certain structure of the liquid, non- zero values of shear stresses, lubricating properties even with their viscosity, which is ten times higher than the viscosity of water. Visualization of the flow of three types of fluids: Newtonian, non-Newtonian power-law and non-Newtonian Herschel-Bulkley type is presented. The use of non- Newtonian fluids makes it possible to reduce the formation of vortices and, as a result, also affects the amount of hydraulic losses in the direction of their reduction.
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Dong, Pu, Ren, Zhai, Gao, and Xie. "Thermoresponsive Bentonite for Water-Based Drilling Fluids." Materials 12, no. 13 (2019): 2115. http://dx.doi.org/10.3390/ma12132115.
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As an important industrial material, bentonite has been widely applied in water-based drilling fluids to create mud cakes to protect boreholes. However, the common mud cake is porous, and it is difficult to reduce the filtration of a drilling fluid at high temperature. Therefore, this paper endowed bentonite with a thermo response via the insertion of N-isopropylacrylamide (NIPAM) monomers. The interaction between NIPAM monomers and bentonite was investigated via Fourier infrared spectroscopy (FTIR), isothermal adsorption, and X-ray diffraction (XRD) at various temperatures. The results demonstrate that chemical adsorption is involved in the adsorption process of NIPAM monomers on bentonite, and the adsorption of NIPAM monomers accords with the D–R model. With increasing temperature, more adsorption water was squeezed out of the composite when the temperature of the composite exceeded 70 °C. Based on the composite of NIPAM and bentonite, a mud cake was prepared using low-viscosity polyanionic cellulose (Lv-PAC) and initiator potassium peroxydisulfate (KPS). The change in the plugging of the mud cake was investigated via environmental scanning electron microscopy (ESEM), contact angle testing, filtration experiments, and linear expansion of the shale at various temperatures. In the plugging of the mud cake, a self-recovery behavior was observed with increasing temperature, and resistance was observed at 110 °C. The rheology of the drilling fluid was stable in the alterative temperature zone (70–110 °C). Based on the high resistance of the basic drilling fluid, a high-density drilling fluid (ρ = 2.0 g/cm3) was prepared with weighting materials with the objective of drilling high-temperature formations. By using a high-density drilling fluid, the hydration expansion of shale was reduced by half at 110 °C in comparison with common bentonite drilling fluid. In addition, the rheology of the high-density drilling fluid tended to be stable, and a self-recovery behavior was observed.
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Yalman, Emine, Tolga Depci, Gabriella Federer-Kovacs, and Hani Al Khalaf. "A new eco-friendly and low cost additive in water based drilling fluids." Rudarsko-geološko-naftni zbornik 36, no. 5 (2021): 1–12. http://dx.doi.org/10.17794/rgn.2021.5.1.
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This study investigates the possibility of using rice husk ash as an additive to develop an environmentally friendly and low-cost drilling fluid system. The rice husk ash was added as an additive to water-based bentonite drilling fluids at different concentrations ranging from 2 wt% to 15 wt%. Rheological and filtration properties of each drilling fluid developed were measured by using a viscometer and standard low-pressure low-temperature filter press. Subsequently, cutting carrying index, minimum annulus velocity required to clean bottom of the well efficiently, flow behaviour index and permeability of mud cakes of the formulated systems were calculated in order to assess performance of the systems. The results demonstrated that the rheological and properties were improved depending on concentration of rice husk ash introduced. With the introduction of 15 wt% concentration of rice husk ash, while apparent viscosity and yield point increased by 60% and 183%, respectively, thixotropy and plastic viscosity decreased by 29% and 63%, respectively. On the other hand, drilling fluid with 4% wt% content of rice husk ash reduced the fluid loss by 10%. Moreover, results showed that cutting carrying index, minimum annulus velocity required to clean bottom of the well efficiently and flow behaviour index of the enhanced with the exploitation of rice husk ash in the drilling fluid. This study showed that rice husk ash as a promising additive to use in the water-based bentonite drilling fluids when properly implemented, and hence reducing the impact on the environment, and the total cost for drilling.
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Lavrentiadi, Yuriy, and Ekaterina Leusheva. "Increasing the Environmental Friendly of Process Fluids Used for Well Drilling." Недропользование 23, no. 1 (2023): 32–43. http://dx.doi.org/10.15593/2712-8008/2023.1.5.
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An important aspect of hydrocarbon drilling is the use of drilling fluids that remove cuttings and stabilize the wellbore, providing better filtration. The properties of drilling fluids are essential to the success of any drilling operation. Fluids were originally developed to enable and cost effectively rotary drilling in subterranean formations. In addition, drilling fluids were designed to form a filter cake, which was primarily designed to reduce filtrate loss to the formation, was thin, and retained the drilling fluid in the wellbore. One of the most important functions of drilling fluids is to minimize the amount of drilling fluid filtrate entering a hydrocarbon containing formation, which can cause damage to the formation due to changes in rock wettability, fines migration, mud plugging with solids, and formation water incompatibility. To stabilize these properties, a number of additives are used in drilling fluids to ensure satisfactory rheological and filtration properties of the fluid. However, the commonly used additives are hazardous to the environment: when drilling fluids are disposed of after drilling operations, they, together with drill cuttings and additives, are discharged into water bodies and cause unwanted pollution. Therefore, these additives should be replaced with additives that are environmentally friendly and provide superior performance. In this regard, biodegradable additives are needed for future research. The review article presents an investigation into the role of various biowastes as potential additives for use in water-based drilling fluids. The use of waste-derived nanomaterial was considered, and rheological and filtration studies of water-based drilling fluids were carried out to evaluate the effect of waste additives on the performance of drilling fluids.
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Liu, Fei, Yongfei Li, Xuewu Wang, and Zhizeng Xia. "Preparation and Properties of Reversible Emulsion Drilling Fluid Stabilized by Modified Nanocrystalline Cellulose." Molecules 29, no. 6 (2024): 1269. http://dx.doi.org/10.3390/molecules29061269.
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Reversible emulsion drilling fluids can concentrate the advantages of water-based drilling fluids and oil-based drilling fluids. Most of the existing reversible emulsion drilling fluid systems are surfactant-based emulsifier systems, which have the disadvantage of poor stability. However, the use of modified nanoparticles as emulsifiers can significantly enhance the stability of reversible emulsion drilling fluids, but ordinary nanoparticles have the disadvantages of high cost and easily causing environmental pollution. In order to solve the shortcomings of the existing reversible emulsion drilling fluid system, the modified nanocrystalline cellulose was considered to be used as an emulsifier to prepare reversible emulsion drilling fluid. After research, the modified nanocrystalline cellulose NWX-3 can be used to prepare reversible emulsions, and on this basis, reversible emulsion drilling fluids can be constructed. Compared with the reversible emulsion drilling fluid stabilized by HRW-DMOB (1.3 vol.% emulsifier), the reversible emulsion drilling fluid stabilized by the emulsifier NWX-3 maintained a good reversible phase performance, filter cake removal, and oily drill cuttings treatment performance with less reuse of emulsifier (0.8 vol.%). In terms of temperature resistance (150 °C) and stability (1000 V < W/O emulsion demulsification voltage), it is significantly better than that of the surfactant system (temperature resistance 120 °C, 600 V < W/O emulsion demulsification voltage < 650 V). The damage of reservoir permeability of different types of drilling fluids was compared by physical simulation, and the damage order of core gas permeability was clarified: water-based drilling fluid > reversible emulsion drilling fluid > oil-based drilling fluid. Furthermore, the NMR states of different types of drilling fluids were compared as working fluids, and the main cause of core permeability damage was the retention of intrusive fluids in the core.
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Li, Hongjiang. "Development and Application of a Novel Green Water-Based Drilling Fluid." Environmental and Earth Sciences Research Journal 8, no. 1 (2021): 61–64. http://dx.doi.org/10.18280/eesrj.080107.
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In response to the technical and environmental protection requirements of water-based drilling fluids, this study independently developed a series of green supporting treatment agents for water-based drilling fluids such as the green loss reducer HB-1, green inhibitor HB-2, and green lubricant HB-3, etc., and proposed a green water-based drilling fluid system (HBDF) with good comprehensive performance. The proposed system has a heat resistance of 150°C, a HTHP (high temperature and high pressure) filtrate loss of 12 mL, a biological toxicity EC50 value greater than 105 mg/L, and a biodegradability BOD5/CODCr value of 16.2%. Now the developed HBDF system has been applied in more than 10 wells in SL oilfield, and the field application results show that the proposed HBDF system has stable rheological and filtrate loss performance, good anti-pollution ability, and easy and simple maintenance operations; after drilling, the biological toxicity of the drilling fluids can meet the environmental protection requirements, which has provided a technical reference for the research of green drilling fluids and the green development of SL Oilfield.
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Hosseini-Kaldozakh, Seyed, Ehsan Khamehchi, Bahram Dabir, Ali Alizadeh, and Zohreh Mansoori. "Experimental Investigation of Water Based Colloidal Gas Aphron Fluid Stability." Colloids and Interfaces 3, no. 1 (2019): 31. http://dx.doi.org/10.3390/colloids3010031.
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Today, the drilling operators use the Colloidal Gas Aphron (CGA) fluids as a part of drilling fluids in their operations to reduce formation damages in low-pressure, mature or depleted reservoirs. In this paper, a Taguchi design of experiment (DOE) has been designed to analyse the effect of salinity, polymer and surfactant types and concentration on the stability of CGA fluids. Poly Anionic Cellulose (PacR) and Xanthan Gum (XG) polymers are employed as viscosifier; Hexadecyl Trimethyl Ammonium Bromide (HTAB) and Sodium Dodecyl Benzene Sulphonate (SDBS) have been also utilized as aphronizer. Moreover, bubble size distributions, rheological and filtration properties of aphronized fluids are investigated. According to the results, the polymer type has the highest effect, whereas the surfactant type has the lowest effect on the stability of CGA drilling fluid. It was also observed that increasing salinity in CGA fluid reduces the stability. Finally, it should be noted that the micro-bubbles generated with HTAB surfactant in an electrolyte system, are more stable than SDBS surfactant.
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Alvi, Muhammad Awais Ashfaq, Mesfin Belayneh, Sulalit Bandyopadhyay, and Mona Wetrhus Minde. "Effect of Iron Oxide Nanoparticles on the Properties of Water-Based Drilling Fluids." Energies 13, no. 24 (2020): 6718. http://dx.doi.org/10.3390/en13246718.
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In recent years, several studies have indicated the impact of nanoparticles (NPs) on various properties (such as viscosity and fluid loss) of conventional drilling fluids. Our previous study with commercial iron oxide NPs indicated the potential of using NPs to improve the properties of a laboratory bentonite-based drilling fluid without barite. In the present work, iron oxide NPs have been synthesized using the co-precipitation method. The effect of these hydrophilic NPs has been evaluated in bentonite and KCl-based drilling fluids. Rheological properties at different temperatures, viscoelastic properties, lubricity, and filtrate loss were measured to study the effect of NPs on the base fluid. Also, elemental analysis of the filtrate and microscale analysis of the filter cake was performed. Results for bentonite-based fluid showed that 0.019 wt% (0.1 g) of NPs reduced the coefficient of friction by 47%, and 0.0095 wt% (0.05 g) of NPs reduced the fluid loss by 20%. Moreover, for KCl-based fluids, 0.019 wt% (0.1 g) of additive reduced the coefficient of friction by 45%, while higher concentration of 0.038 wt% (0.2 g) of NPs shows 14% reduction in the filtrate loss. Microscale analysis shows that presence of NPs in the cake structure produces a more compact and less porous structure. This study indicates that very small concentration of NPs can provide better performance for the drilling fluids. Additionally, results from this work indicate the ability of NPs to fine-tune the properties of drilling fluids.
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Ismail, Abdul Razak, Wan Rosli Wan Sulaiman, Mohd Zaidi Jaafar, Issham Ismail, and Elisabet Sabu Hera. "Nanoparticles Performance as Fluid Loss Additives in Water Based Drilling Fluids." Materials Science Forum 864 (August 2016): 189–93. http://dx.doi.org/10.4028/www.scientific.net/msf.864.189.
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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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Wang, Zhongyi, Jinsheng Sun, Kaihe Lv, Xianbin Huang, Zhenhang Yuan, and Yang Zhang. "Mechanisms of Low Temperature Thickening of Different Materials for Deepwater Water-Based Drilling Fluids." Gels 10, no. 12 (2024): 789. https://doi.org/10.3390/gels10120789.
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During deepwater drilling, the low mudline temperatures and narrow safe density window pose serious challenges to the safe and efficient performance of deepwater water-based drilling fluids. Low temperatures can lead to physical and chemical changes in the components of water-based drilling fluids and the behavior of low temperature gelation. As a coarse dispersion system, water-based drilling fluid has a complex composition of dispersed phase and dispersing medium. Further clarification of low temperature gelation would be helpful in developing technical approaches to enhance the flat rheology performance of deepwater water-based drilling fluids. In this paper, different components are separated in order to comprehensively analyze the gelation behavior of different materials in water-based drilling fluids at low temperatures. In the first place, the rheological and hydrodynamic radius alterations of inorganic salts, bentonite, and additives in aqueous solutions were examined at low temperatures. The effects of inorganic salts, bentonite, and additives on the purified water system were investigated at low (4 °C)–normal (25 °C)–high (75 °C) temperatures. The low temperature gelation of different materials in pure water systems are fully clarified. The mud containing 4% bentonite with weak low temperature gelation commonly used in deepwater water-based drilling fluids was selected as the basic test system. Inorganic salts, additives, and solid-phase materials were added to the mud containing 4% bentonite. The effects of the interactions between different materials and bentonite particles on the low temperature gelation behavior of mud were analyzed. The higher the bentonite dosage, the stronger the low temperature gelation behavior of mud. The higher the addition of inorganic salts, the more serious the low temperature gelation behavior of mud. Inorganic salts should be avoided as much as possible to add too much. The low temperature gelation behavior of mud with low-viscosity additives is weak. However, the viscosity of mud with high-viscosity additives has a small change in viscosity with increasing temperature. The low temperature gelation of mud with the addition of solid-phase particulate materials with reactive groups on the surface is strong, and the low temperature gelation with the addition of inert particles is weak. This paper elucidates the low temperature gelation mechanism of bentonite, inorganic salts, additives, and solid-phase materials in deepwater water-based drilling fluids. The conclusion can also be used to guide the construction of a drilling fluid system, which is of great significance for the research and development of deepwater water-based drilling fluid additives and the safe and efficient performance of deepwater drilling fluids.
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Al-Ghanimi, Ghofran F., and Nada S. Al-Zubaidi. "Effect of Ferric Oxide and Magnesium Oxide Nanoparticles on Iraqi Bentonite Performance in Water Based Drilling Fluid." Association of Arab Universities Journal of Engineering Sciences 27, no. 2 (2020): 14–23. http://dx.doi.org/10.33261/jaaru.2020.27.2.002.
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In oil and gas industry, the nanotechnology has been applied in different fields. Reservoir, exploration, drilling, completion, production, processing, and refinery are nanotechnology applications fields. Nanoparticles materials are one of the areas that are utilized in preparing drilling fluids. These nanomaterials are used to formulate high performance drilling fluids. In other words, these nano particles materials can be used to design smart drilling fluids. The properties of these drilling fluids can be met the well conditions requirements. The aim of this study is to enhance the performance of Iraqi bentonite in drilling fluids using nanomaterials. Iraqi calcium montmorillonite clay (Ca- bentonite) from Wadi Bashera in Iraqi Western Desert was obtained and studied in order to use it as an alternative active solid to the imported commercial bentonite. Water based drilling fluids were prepared with 3, 6, and 12 wt. % of Iraqi bentonite. Mgnesium oxide nanoparticles (MgO NPs) and ferric oxide nanoparticles (Fe2O3 NPs) with different concentrations were used. The experimental work showed that, MgO NPs resulted in a significant increase in the rheological properties of drilling fluids prepared with 3 and 6 wt. % of Iraqi bentonite. In contrast, moderate effect on the rheological properties of drilling fluid prepared with 12 wt. % of Iraqi bentonite were obtained with low concentrations of Fe2O3 NPs. Basically drilling fluids prepared with Iraqi bentonite had extreme filtrate volume compared with API specifications and poor controlling to filtration properties were obtained with MgO NPs and Fe2O3 NPs additions. The impact of these two nanomaterials was revealed on the stability of drilling fluids prepared with Iraqi bentonite, where an enhancemment from 65 % to 100% was observed.
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Błaż, Sławomir, Grzegorz Zima, Bartłomiej Jasiński, and Marcin Kremieniewski. "Invert Drilling Fluids with High Internal Phase Content." Energies 14, no. 15 (2021): 4532. http://dx.doi.org/10.3390/en14154532.
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One of the most important tasks when drilling a borehole is to select the appropriate type of drilling fluid and adjust its properties to the borehole’s conditions. This ensures the safe and effective exploitation of the borehole. Many types of drilling fluids are used to drill holes for crude oil and natural gas. Most often, mainly due to cost and environmental constraints, water-based muds are used. On the other hand, invert drilling fluids are used for drilling holes in difficult geological conditions. The ratio of the oil phase to the water phase in invert drilling fluids the most common ratio being from 70/30 to 90/10. One of the disadvantages of invert drilling fluids is their cost (due to the oil content) and environmental problems related to waste and the management of oily cuttings. This article presents tests of invert drilling fluids with Oil-Water Ratio (OWR) 50/50 to 20/80 which can be used for drilling HPHT wells. The invert drilling fluids properties were examined and their resistance to temperature and pressure was assessed. Their effect on the permeability of reservoir rocks was also determined. The developed invert drilling fluids are characterized by high electrical stability ES above 300 V, and stable rheological parameters and low filtration. Due to the reduced content of the oil, the developed drilling fluid system is more economical and has limited toxicity.
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Leite, Raquel Santos, Ana Paula Tertuliano Dantas, and Luciana Viana Amorim. "Influence of Clay Swelling Inhibitor in Filtration Properties of Water-Based Drilling Fluids." Materials Science Forum 869 (August 2016): 1018–22. http://dx.doi.org/10.4028/www.scientific.net/msf.869.1018.
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This work aims to evaluate the influence of the clay swelling inhibitor in the filtration properties of water-based drilling fluids. Drilling fluids were prepared with and without adding potassium citrate clay inhibitor. The following additives were used in the composition of the fluid: viscosity agent (xanthan gum), filtrate reducer (starch and low viscosity carboxymethylcellulose (CMC LV)), antifoam, bactericide, sealant (calcite), lubricant and pH controller. The concentration of inhibitor was used of 15, 20, 25 and 30 g/ 350 mL of water. We determined the filtration properties (filtrate volume (FV), spurt loss (SL), cake thickness (CT) and permeability (K)) of drilling fluids. According to the results, it was concluded that: (i) adding the inhibitor to the fluid promoted reduction of FV and K of fluids containing starch in the composition and (ii) the inhibitor promoted satisfactory reductions in the CT and increased of SL for all the studied fluids. Finally, the inhibited fluids prepared with higher concentrations of starch, CMC LV, calcite and potassium citrate than 25 g/ 350 mL of water showed the best performance compared to FV and SL.
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Peng, Chunyao, Wenqiang Feng, Xiaohu Luo, Shujiao Li, and Chen Riji. "An Environmentally Friendly Wbm System Can Prevent Hard Brittle Shale Instability." Scientific Contributions Oil and Gas 32, no. 2 (2022): 133–42. http://dx.doi.org/10.29017/scog.32.2.843.
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In the Weizhou Southwest oilfields, drilling delays and suspension of wells prior to reaching the targets due to wellbore instability had occurred frequently. The hard brittle shale played a problematic role. Conventional water-based drilling fluids didn’t conquer the problematic formation due to intrinsically performance deficiencies. While Oil based drilling fluids are routinely preferred in the more technically demanding applications, they are cause for increasing concern due to offshore environmental restrictions and expensive disposal costs. An environmentally acceptable water-based drilling fluid was developed to challenge the problematic formation based on the combination of methylglucoside-silicate concept. It stabilized the reactive shale by the same mechanism as did oil-based drilling fluid in preventing shale hydration, pore pressure increase and weakening of shale by effectively developing sufficient osmotic force to offset hydraulic and chemical forces acting to cause filtration flux into the hard brittle shale. A field trial was initiated on the CNOOC 931 platform in Weizhou oilfield. The data from the pilot well showed that the novel drilling fluid exhibited excellent inhibition and lubricity which approached or even exceeded oil-based fluids.
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TO., Ozoude. "Assessment of drilling fluids toxicity on Escherichia coli and Pseudomonas spp. in marine water from Akwa Ibom State, Nigeria." Journal of Biodiversity and Environmental Sciences (JBES) 22, no. 4 (2023): 152–57. https://doi.org/10.5281/zenodo.10403793.
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The contamination of environments with various kinds of petroleum products has been a long – term practice and as such can affect the role of microbes in food chain and as agents of biodegradation of substances in aquatic ecosystems. The acute toxicity of drilling fluids, water -based and oil-based, was assessed on <em>Escherichia coli</em> and <em>Pseudomonas </em>spp<em>.</em> The test organisms were isolated from marine water by spread plate technique and further confirmed by growth on eosin methylene blue and cetrimide agar for <em>Escherichia coli</em> and <em>Pseudomonas </em>spp respectively. Percentage log survival was used as index for toxicity assessment. The result of the study revealed a decrease in percent log survival of the test isolates as the concentration of the toxicants and time of exposure increased. A stimulatory effect was observed for <em>Pseudomonas </em>spp and <em>Escherichia coli</em> in oil-based drilling fluid at 1,000ppm concentration during the 0- and 8-hour exposure periods and 100ppm during 24 – hour exposure period, respectively. The significance of the toxicity of the fluids to the susceptibility of the test isolates was analyzed by ANOVA using SPSS and the result revealed that the isolates were susceptible to the fluids concentrations at varying degrees. The result of the LC<sub>50</sub> of the drilling fluids revealed water – based drilling fluid to be less toxic than oil – based drilling fluid to both isolates; <em>Escherichia coli</em> (168.77ppm, 15. 431ppm) and <em>Pseudomonas </em>spp (5776.69ppm, 372.92ppm), respectively. The higher the LC<sub>50 </sub>the lower the toxicity. published by the <strong>Journal of Biodiversity and Environmental Science (JBES)</strong>
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Carpenter, Chris. "High-Temperature Water-Based Drilling Fluid Accesses Depleted Deepwater Reserves." Journal of Petroleum Technology 74, no. 11 (2022): 59–61. http://dx.doi.org/10.2118/1122-0059-jpt.
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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 207825, “First Use of Novel High-Temperature Water-Based Reservoir Drilling Fluid To Access Depleted Deepwater Reserves,” by Alexandra C. Morrison, Conan King, SPE, and Kevin Rodrigue, Halliburton. The paper has not been peer reviewed. _ A combination of divalent base brine and high wellbore temperature presents significant challenges for high-density aqueous reservoir drilling fluids. Such systems traditionally use biopolymers as viscosifiers; however, they are subject to degradation at elevated temperatures. Nonaqueous drilling fluids are thermally stable, but complete removal of the filter cake is challenging, which can lead to formation damage. The complete paper describes the qualification and first deepwater drilling application of an aqueous reservoir drilling fluid at temperatures greater than 320°F. Introduction The laboratory development and scale-up yard trials of the high-temperature divalent brine-based reservoir drilling fluid (HT-RDF) and solids-free screen running fluid (SF-SRF) systems used for this well took several years. Specific rheology and fluid-loss targets were set and met during the design phase, and, in conjunction with hydraulic modeling, software simulations demonstrated that equivalent circulating densities (ECDs) would be acceptable based on well-construction plans. The HT-RDF showed excellent thermal stability in static age tests, which was crucial because of the plans for openhole logging of the production zone once total depth was reached. Screen plugging was identified early in the project as a key risk; the most-suitable mitigation for this was to engineer a completely solids-free fluid in which to install the sand screens. The resulting SF-SRF was designed to provide fluid-loss control and wellbore stability in case filter cake was stripped from the formation face during the screen run. Finally, given the focus on production maximization, the fluids underwent rigorous formation-damage tests, ultimately showing that a return permeability of greater than 60% was possible with the inclusion of an acid breaker to assist filter-cake dissolution.
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Basfar, Salem, Ashraf Ahmed, and Salaheldin Elkatatny. "Utilization of Vermiculite for Solving Hematite Sagging in Water-Based Drilling Fluids." Geofluids 2022 (September 30, 2022): 1–9. http://dx.doi.org/10.1155/2022/5277126.
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The sagging phenomenon of solids, such as hematite, in drilling fluids is commonly experienced when drilling at elevated temperature conditions presenting operational and well control issues. Thus, we report herein the addition of vermiculite to water-based drilling fluid with the objective of improving fluid stability by hematite sagging mitigation. Different quantities of vermiculite clay (3–6 lb/bbl) were used and the sagging tendency was evaluated for the base and vermiculite-containing drilling fluids under static and dynamic conditions. From the sag measurements, the optimum vermiculite content was determined, and the influence on the key drilling fluid properties was studied by conducting the rheology, viscoelasticity, filtration, density, and alkalinity measurements. To simulate the practical elevated temperature, the tests were performed at temperature up to 250°F. The outcomes of this study revealed that the addition of vermiculite to the base drilling fluid significantly improved fluid stability. The content of 5 lb/bbl vermiculite was sufficient to mitigate the hematite sagging at elevated temperatures and drive the sag tendency factors to safe values. The ability of vermiculite to improve fluid stability was confirmed with the enhancement of rheological and viscoelastic properties, since the recommended vermiculite content resulted in a 24% reduction in plastic viscosity, 9% increment on yield point, and improved storage and loss modulus with better gelling structure. Also, the filtration properties were improved with 5 lb/bbl vermiculite, as the filtrated volume was reduced from 6.2 to 5 cm3 and formulated a preferred filter cake with less weight and thickness. In addition, the small amount of vermiculite did not change the drilling fluid weight, and the pH was slightly dropped but within the practical alkalinity range.
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Ospanov, Yerlan Kanatovich, Gulzhan Abdullaevna Kudaikulova, Murat Smanovich Moldabekov, and Moldir Zhumabaevna Zhaksylykova. "Improving Shale Stability through the Utilization of Graphene Nanopowder and Modified Polymer-Based Silica Nanocomposite in Water-Based Drilling Fluids." Processes 12, no. 8 (2024): 1676. http://dx.doi.org/10.3390/pr12081676.
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Shale formations present significant challenges to traditional drilling fluids due to fluid infiltration, cuttings dispersion, and shale swelling, which can destabilize the wellbore. While oil-based drilling fluids (OBM) effectively address these concerns about their environmental impact, their cost limits their widespread use. Recently, nanomaterials (NPs) have emerged as a promising approach in drilling fluid technology, offering an innovative solution to improve the efficiency of water-based drilling fluids (WBDFs) in shale operations. This study evaluates the potential of utilizing modified silica nanocomposite and graphene nanopowder to formulate a nanoparticle-enhanced water-based drilling fluid (NP-WBDF). The main objective is to investigate the impact of these nanoparticle additives on the flow characteristics, filtration efficiency, and inhibition properties of the NP-WBDF. In this research, a silica nanocomposite was successfully synthesized using emulsion polymerization and analyzed using FTIR, PSD, and TEM techniques. Results showed that the silica nanocomposite exhibited a unimodal particle size distribution ranging from 38 nm to 164 nm, with an average particle size of approximately 72 nm. Shale samples before and after interaction with the graphene nanopowder WBDF and the silica nanocomposite WBDF were analyzed using scanning electron microscopy (SEM). The NP-WBM underwent evaluation through API filtration tests (LTLP), high-temperature/high-pressure (HTHP) filtration tests, and rheological measurements conducted with a conventional viscometer. Experimental results showed that the silica nanocomposite and the graphene nanopowder effectively bridged and sealed shale pore throats, demonstrating superior inhibition performance compared to conventional WBDF. Post adsorption, the shale surface exhibited increased hydrophobicity, contributing to enhanced stability. Overall, the silica nanocomposite and the graphene nanopowder positively impacted rheological performance and provided favorable filtration control in water-based drilling fluids.
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Luo, Taotao, Jun Li, Jiangen Xu, Jun Wang, Lianxi Zhang, and Zeya Yu. "The Effects of Organically Modified Lithium Magnesium Silicate on the Rheological Properties of Water-Based Drilling Fluids." Materials 17, no. 7 (2024): 1564. http://dx.doi.org/10.3390/ma17071564.
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To address the problem of insufficient temperature and salt resistance of existing polymer viscosity enhancers, we designed an organic–inorganic hybrid composite as a viscosity enhancer for water-based drilling fluids, named LAZ, and it was prepared by combining a water-soluble monomer and lithium magnesium silicate (LMS) using an intercalation polymerization method. The composite LAZ was characterized using Fourier transform infrared spectroscopy, transformed target X-ray diffractometry, scanning electron microscopy, and thermogravimetric analysis. The rheological properties of the composite LAZ were evaluated. The composite LAZ was used as a water-based drilling fluid viscosity enhancer, and the temperature and salt resistance of the drilling fluid were evaluated. The results showed that the composite LAZ presented a complex reticulation structure in an aqueous solution. This reticulation structure intertwined with each other exhibited viscosity-enhancing properties, which can enhance the suspension properties of water-based drilling fluids. The aqueous solution of the composite LAZ has shear dilution properties. As shear rate increases, shear stress becomes larger. The yield stress value of the aqueous solution increases as the composite LAZ’s concentration increases. The aqueous solution of the composite LAZ exhibits strong elastic characteristics with weak gel properties. The addition of the composite LAZ to 4% sodium bentonite-based slurry significantly increased the apparent viscosity and dynamic shear of the drilling fluid. The drilling fluids containing the composite LAZ had good temperature resistance at 150 °C and below. The rheological properties of brine drilling fluids containing the composite LAZ changed slightly before and after high-temperature aging at 150 °C.
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Li, Zuo Chen, Zhi Heng Zhang, Liang Zhan, and Jia Rong Cai. "Fuzzy Ball Drilling Fluids for CBM in the Ordos Basin of China." Advanced Materials Research 602-604 (December 2012): 843–46. http://dx.doi.org/10.4028/www.scientific.net/amr.602-604.843.
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Fuzzy ball drilling fluids have been developed in order to effectively control lost circulation during CBM drilling. Depending upon fuzzy balls and colloids in fuzzy balls, the fuzzy ball drilling fluids changed their shapes and properties to completely plug underground heterogeneous seepage channels so as to strengthen the pressure bearing capacity of formations. This paper describes the available features of the fuzzy ball drilling fluid including efficient plugging, good carrying and suspension, formation damage control, compatible weighted by any weighted materials without auxiliary equipment. The fuzzy ball drilling fluids can finish drilling in low pressure natural gas zone, control CBM leakage; control the natural fractures, drilling in different pressures in the same open hole, combination with the air drilling mode, etc. during Ordos CBM drilling. The fuzzy ball drilling fluid will not affect down-hole motors and MWD. The fuzzy ball drilling fluid will be blend simply as conventional water based drilling fluids. The existing CBM drilling equipment can completely meet the fuzzy ball drilling mixing and it is maintained conveniently. The fuzzy ball drilling fluid is the efficient drilling fluid.
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Wang, Jin Feng, and Jin Gen Deng. "Fuzzy Ball Drilling Fluid for CBM in the Ordos Basin of China." Advanced Materials Research 651 (January 2013): 717–21. http://dx.doi.org/10.4028/www.scientific.net/amr.651.717.
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Fuzzy ball drilling fluids have been developed in order to effectively control lost circulation during CBM drilling. Depending upon fuzzy balls and colloids in fuzzy balls, the fuzzy ball drilling fluids changed their shapes and properties to completely plug underground heterogeneous seepage channels so as to strengthen the pressure bearing capacity of formations. This paper describes the available features of the fuzzy ball drilling fluid including efficient plugging, good carrying and suspension, formation damage control, compatible weighted by any weighted materials without auxiliary equipment. The fuzzy ball drilling fluids can finish drilling in low pressure natural gas zone, control CBM leakage; control the natural fractures, drilling in different pressures in the same open hole, combination with the air drilling mode, etc. during Ordos CBM drilling. The fuzzy ball drilling fluid will not affect down-hole motors and MWD. The fuzzy ball drilling fluid will be blend simply as conventional water based drilling fluids. The existing CBM drilling equipment can completely meet the fuzzy ball drilling mixing and it is maintained conveniently. The fuzzy ball drilling fluid is the efficient drilling fluid.
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Mohamed, Abdelmjeed, Saad Al-Afnan, Salaheldin Elkatatny, and Ibnelwaleed Hussein. "Prevention of Barite Sag in Water-Based Drilling Fluids by A Urea-Based Additive for Drilling Deep Formations." Sustainability 12, no. 7 (2020): 2719. http://dx.doi.org/10.3390/su12072719.
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Barite sag is a challenging phenomenon encountered in deep drilling with barite-weighted fluids and associated with fluid stability. It can take place in vertical and directional wells, whether in dynamic or static conditions. In this study, an anti-sagging urea-based additive was evaluated to enhance fluid stability and prevent solids sag in water-based fluids to be used in drilling, completion, and workover operations. A barite-weighted drilling fluid, with a density of 15 ppg, was used with the main drilling fluid additives. The ratio of the urea-based additive was varied in the range 0.25–3.0 vol.% of the total base fluid. The impact of this anti-sagging agent on the sag tendency was evaluated at 250 °F using vertical and inclined sag tests. The optimum concentration of the anti-sagging agent was determined for both vertical and inclined wells. The effect of the urea-additive on the drilling fluid rheology was investigated at low and high temperatures (80 °F and 250 °F). Furthermore, the impact of the urea-additive on the filtration performance of the drilling fluid was studied at 250 °F. Adding the urea-additive to the drilling fluid improved the stability of the drilling fluid, as indicated by a reduction in the sag factor. The optimum concentration of this additive was found to be 0.5–1.0 vol.% of the base fluid. This concentration was enough to prevent barite sag in both vertical and inclined conditions at 250 °F, with a sag factor of around 0.5. For the optimum concentration, the yield point and gel strength (after 10 s) were improved by around 50% and 45%, respectively, while both the plastic viscosity and gel strength (after 10 min) were maintained at the desired levels. Moreover, the anti-sagging agent has no impact on drilling fluid density, pH, or filtration performance.
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Li, Jian, Jinsheng Sun, Kaihe Lv, et al. "Temperature- and Salt-Resistant Micro-Crosslinked Polyampholyte Gel as Fluid-Loss Additive for Water-Based Drilling Fluids." Gels 8, no. 5 (2022): 289. http://dx.doi.org/10.3390/gels8050289.
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With increasing global energy consumption, oil/gas drilling has gradually expanded from conventional shallow reservoirs to deep and ultra-deep reservoirs. However, the harsh geological features including high temperature and high salinity in ultra-deep reservoirs have become a critical challenge faced by water-based drilling fluids (WDFs), which seriously deteriorate the rheology and fluid loss properties, causing drilling accidents, such as wellbore instability and formation collapse. In this study, a novel temperature- and salt-resistant micro-crosslinked polyampholyte gel was synthesized using N,N-dimethylacrylamide, diallyldimethyl ammonium chloride, 2-acrylamido-2-methylpropanesulfonic acid, maleic anhydride and chemical crosslinking agent triallylamine through free radical copolymerization. Due to the synergistic effect of covalent micro-crosslinking and the reverse polyelectrolyte effect of amphoteric polymers, the copolymer-based drilling fluids exhibit outstanding rheological and filtration properties even after aging at high temperatures (up to 200 °C) and high salinity (saturated salt) environments. In addition, the zeta potential and particle size distribution of copolymer-based drilling fluids further confirmed that the copolymer can greatly improve the stability of the base fluid suspension, which is important for reducing the fluid-loss volume of WDFs. Therefore, this work will point out a new direction for the development of temperature- and salt-resistant drilling fluid treatment agents.
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Xie, Wenbing, and Jacqueline Lecourtier. "Xanthan behaviour in water-based drilling fluids." Polymer Degradation and Stability 38, no. 2 (1992): 155–64. http://dx.doi.org/10.1016/0141-3910(92)90009-t.
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Ikram, Rabia, Badrul Mohamed Jan, Akhmal Sidek, and George Kenanakis. "Utilization of Eco-Friendly Waste Generated Nanomaterials in Water-Based Drilling Fluids; State of the Art Review." Materials 14, no. 15 (2021): 4171. http://dx.doi.org/10.3390/ma14154171.
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An important aspect of hydrocarbon drilling is the usage of drilling fluids, which remove drill cuttings and stabilize the wellbore to provide better filtration. To stabilize these properties, several additives are used in drilling fluids that provide satisfactory rheological and filtration properties. However, commonly used additives are environmentally hazardous; when drilling fluids are disposed after drilling operations, they are discarded with the drill cuttings and additives into water sources and causes unwanted pollution. Therefore, these additives should be substituted with additives that are environmental friendly and provide superior performance. In this regard, biodegradable additives are required for future research. This review investigates the role of various bio-wastes as potential additives to be used in water-based drilling fluids. Furthermore, utilization of these waste-derived nanomaterials is summarized for rheology and lubricity tests. Finally, sufficient rheological and filtration examinations were carried out on water-based drilling fluids to evaluate the effect of wastes as additives on the performance of drilling fluids.
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Kök, Onur Eser. "INVESTIGATION OF QUARTZ SAND AS FILTRATION REDUCER IN DRILLING FLUIDS." Geosound, no. 61 (June 23, 2025): 39–50. https://doi.org/10.70054/geosound.1666845.
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Drilling operations are very important for production and utilization of primary energy resources and directly interacting with drilling fluid. Therefore, efficient drilling fluid is required for successful drilling. The flow properties of drilling fluid vary depending on many parameters, especially filtration properties. In this study, investigated the usability of commercial quartz sand as a filtration-reducing additive material in water-based drilling fluids. In the experimental studies, spud-type drilling fluids were prepared suitable for drilling applications, and then quartz sands were added at different ratios (0.25-0.50-1.0-1.5-2.0 wt.%). Then, filtration measurements were performed at different times (15-30-60 min). As a result of the measurements, it has been determined that quartz sand has a significant filtration-reducing effect and can be used in spud-type drilling fluids.
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Guliyev, V. V. "Enhancement lubricity properties of water-based mud with nanoparticles." Azerbaijan Oil Industry, no. 10 (October 15, 2020): 70–74. http://dx.doi.org/10.37474/0365-8554/2020-10-70-74.
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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.
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T. N., Godloves, Ebri R. U., Ihua-Maduenyi I. E., and Alerechi U.P. "Enhancement of Water Based Mud Cutting Carrying Capacity Using Aluminium Oxide (Al2o3) Nanoparticle." Universal Library of Engineering Technology 01, no. 02 (2024): 01–07. http://dx.doi.org/10.70315/uloap.ulete.2024.0102001.
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This research seeks to determine how much Al2O3 nanoparticles can alter the rheological properties and cutting carrying capacity of bentonite-water drilling fluids when different concentration is applied. The aim is to explore these phenomena. The purpose of the research is to produce and describe drilling fluid using nanoparticles and evaluate its cutting-capture capability. The study examined the physiochemical, rheological, and filtration properties, as well as the cutting carry index (CCI) of samples produced from drilling in various concentrations of Al2O3nanoparticles. The control mud was created using bentonite with a concentration of 2.8g (0% Al2O3) without any nanoparticles. Al2O3 was discovered to enhance the plastic viscosity, apparent viscousness, and yield point, but inhibit the gel strength of the drilling fluid. Nevertheless, The Power Law Model was used to describe the Rheological behavior of the prepared mud samples, with a flow behavior index (n) less than 1, which indicated that the formulated muddy samples were all pseudo plastic fluids, ideally suitable for drilling fluid. According to the study, the addition of MgO and Al2O3 nanoparticles can affect the cutting carrying index, resulting in a high-cutting carrying Index that enhances the hole cleaning potential of the drilling mud. The findings of this study indicate a high cutting carrying capacity index, indicating the feasibility of using nanoparticles in drilling operations.
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Liu, Jingping, Zhiwen Dai, Ke Xu, et al. "Water-Based Drilling Fluid Containing Bentonite/Poly(Sodium 4-Styrenesulfonate) Composite for Ultrahigh-Temperature Ultradeep Drilling and Its Field Performance." SPE Journal 25, no. 03 (2020): 1193–203. http://dx.doi.org/10.2118/199362-pa.
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Summary The rapidly increasing global oil/gas demand and gradual depletion of shallow reservoirs require the development of deep oil/gas reservoirs and geothermal reservoirs. However, deep drilling suffers from drilling-fluid failures under ultrahigh temperature, which cause serious accidents such as wellbore collapse, stuck pipe, and even blowouts. In this study, we revealed the role of polymeric additives in improving the ultrahigh-temperature tolerance of bentonite-based drilling fluids, aiming to provide practical and efficient solutions to the failure of drilling fluids in severe conditions. By adding poly(sodium 4-styrenesulfonate) (PSS) to the original drilling fluid containing bentonite, significant fluid loss—as a consequence of bentonite-particle flocculation causing drilling-fluid shear-stress reduction and high-permeability mud—is successfully suppressed even at temperature as high as 200°C. This drilling fluid containing PSS was applied in the drilling of high-temperature deep wells in Xinjiang province, China, and exhibited high effectiveness in controlling accidents including overflow and leakage. NOTE: A supplementary file is available in the Supporting Information section.
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Amalate Ann Obuebite, Adaobi Stephenie Nwosi-Anele, and Sunday Igbani. "Enhancement of rheological properties and cutting carrying capacity of water based drilling fluid using Al2O3 nanoparticles." Global Journal of Engineering and Technology Advances 14, no. 3 (2023): 138–48. http://dx.doi.org/10.30574/gjeta.2023.14.3.0055.
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Drilling mud is a necessary component of drilling operations. There have been notable attempts to enhance the filtration and rheological properties and increase the cutting carrying capacity of water-based mud (WBM) using nanoparticles (NPs). This study investigates how varying Al2O3 concentrations affect the rheological properties and cutting carrying capacity of drilling fluids. In this study, different drilling muds were produced using bentonite (2.8g) without nanoparticle, 50% bentonite (1.4g) and 50% Al2O3(1.4) and 0% bentonite(0g) and 100% Al2O3 (2.8g). Testing and comparisons were done on the formed mud samples' physiochemical properties, rheology, filtration properties, and cutting carry index (CCI). The Power Law Model was used to define the rheological behavior of the manufactured mud samples, and results showed that all the mud samples were pseudoplastic fluids and remain a preference for drilling fluids because their flow behavior index (n) was less than 1. It was observed that the addition of Al2O3 is directly proportional to the plastic viscosity, apparent viscosity and yield point and inversely proportional to the gel strength of the drilling fluid. The study also shows that the addition of Al2O3 nanoparticle influences the cutting carrying index CCI as the calculated cutting carrying index gives a high cutting carrying index CCI which means that the hole cleaning potential of the drilling mud is good. The study shows that Al2O3 nanoparticles are feasible for use in drilling fluid formulation.
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Nee, Lim Symm, Badrul Mohamed Jan, Brahim Si Ali, and Ishenny Mohd Noor. "The Effects of Glass Bubbles, Clay, Xanthan Gum and Starch Concentrations on the Density of Lightweight Biopolymer Drilling Fluid." Applied Mechanics and Materials 625 (September 2014): 526–29. http://dx.doi.org/10.4028/www.scientific.net/amm.625.526.
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It is an open secret that currently oil and gas industry is focusing on increasing hydrocarbon production through underbalanced drilling (UBD) and finding ways to ensure the drilling process is less harmful to the environment. Water-based biopolymer drilling fluids are preferred compared to oil based drilling fluids owing to the fact that it causes less pollution to the environment. This paper investigates the effects of varying concentrations of environmentally safe raw materials, namely glass bubbles, clay, xanthan gum and starch concentrations on the density of the formulated biopolymer drilling fluid to ensure that it is suitable for UBD. As material concentrations were varied, the density for each sample was measured at ambient temperature and pressure. Results showed that the final fluid densities are within acceptable values for UBD (6.78 to 6.86 lb/gal). It is concluded that the formulated water-based biopolymer drilling fluid is suitable to be used in UBD operation.
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Ai, Erxin, Qi Li, Zhikun Liu, Bo Zhang, Liupeng Wang, and Chengyun Ma. "Advanced Trends in Shale Mechanical Inhibitors for Enhanced Wellbore Stability in Water-Based Drilling Fluids." Minerals 14, no. 12 (2024): 1197. http://dx.doi.org/10.3390/min14121197.
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Wellbore instability, particularly in shale formations, presents a great challenge to modern drilling operations. Although conventional chemical inhibitors are frequently employed in water-based drilling fluids, they may not always function in highly reactive or naturally fractured shale formations. In recent years, mechanical inhibitors have attracted attention as a complementary solution to chemical methods. These inhibitors, which include carbon-based, silicon-based, metal-based, and mineral-based particle materials, provide structural support to the wellbore by physically plugging fractures and sealing microfractures. This paper presents a comprehensive review of the mineral types associated with shale wellbore instability as well as a critical analysis of the mechanisms, categories, and effectiveness of mechanical inhibitors in enhancing wellbore stability. The development challenges and prospects of mechanical inhibitors in water-based drilling fluids are also discussed. This review emphasizes the potential of mechanical inhibitors in reducing fluid invasion, preventing wellbore collapse, and improving overall drilling efficiency, which will help facilitate the development and large-scale application of mechanical inhibitors in drilling fluids.
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Dai, Zhiwen, Jinsheng Sun, Jingping Liu, et al. "Study on the Inhibition Mechanism of Hydration Expansion of Yunnan Gas Shale using Modified Asphalt." Materials 17, no. 3 (2024): 645. http://dx.doi.org/10.3390/ma17030645.
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Drilling fluids play an essential role in shale gas development. It is not possible to scale up the use of water-based drilling fluid in shale gas drilling in Yunnan, China, because conventional inhibitors cannot effectively inhibit the hydration of the illite-rich shale formed. In this study, the inhibition performance of modified asphalt was evaluated using the plugging test, expansion test, shale recovery experiment, and rock compressive strength test. The experimental results show that in a 3% modified asphalt solution, the expansion of shale is reduced by 56.3%, the recovery is as high as 97.8%, water absorption is reduced by 24.3%, and the compression resistance is doubled compared with those in water. Moreover, the modified asphalt can effectively reduce the fluid loss of the drilling fluid. Modified asphalt can form a hydrophobic membrane through a large amount of adsorption on the shale surface, consequently inhibiting shale hydration. Simultaneously, modified asphalt can reduce the entrance of water into the shale through blocking pores, micro-cracks, and cracks and further inhibit the hydration expansion of shale. This demonstrates that modified asphalt will be an ideal choice for drilling shale gas formations in Yunnan through water-based drilling fluids.
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Fadhil, Elaf, and Farqad Hadi. "Biodegradable Shale Inhibitors for Water Based Fluids." Iraqi Geological Journal 57, no. 2E (2024): 236–51. https://doi.org/10.46717/igj.57.2e.18ms-2024-11-27.
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Swelling of shale formations is the main challenge may be encountered during the drilling operations. To address this challenge, the potassium chloride (KCl) is traditionally added as an inhibitor to the drilling mud for controlling its chemical reaction with the shale formations. However, environmental concerns surrounding the non-biodegradability and detrimental effects of chloride ions necessitate the exploration of alternative solutions. This study focuses on evaluating the efficiency of biodegradable and environmentally friendly additives in mitigating the shale swelling. Potassium sorbate, potassium citrate, and potassium bicarbonate are the selective additives with different concentrations (1%-7%). Different tests, including X-ray diffraction and X-ray fluorescence, were conducted to characterize the shale type and determine its chemical composition or the major mineral abundances. Additionally, scanning electron microscopy was employed to analyze the microstructure of shale cuttings and identify the small-scale pore features. Furthermore, cation exchange capacity measurements were performed to ascertain the shale samples' ion exchange capabilities. The effectiveness of the additives was evaluated using the Linear Swell Test. The results revealed that potassium sorbate exhibited a remarkable performance in reducing shale swelling, its consistently yielding the lowest swelling percentage compared to other tested materials. A concentration of 4% of potassium sorbate demonstrated the lowest reduction in swelling that reaches to 3.938%. Additionally, potassium citrate and potassium bicarbonate exhibited swelling rates close to those observed with KCl. The lowest swelling percentage achieved at different concentrations of potassium citrate (4% and 5%) was 12.019%. In contrast, a 11.819% of swelling percent was observed when 5% concentration of potassium bicarbonate was added to the drilling mud. This research introduces innovation biodegradable materials added to the drilling mud for mitigating the shale swelling.
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Ali, Muhammad, Husna Hayati Jarni, Adnan Aftab, et al. "Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review." Energies 13, no. 13 (2020): 3417. http://dx.doi.org/10.3390/en13133417.
Full textAbstract:
The world’s energy demand is steadily increasing where it has now become difficult for conventional hydrocarbon reservoir to meet levels of demand. Therefore, oil and gas companies are seeking novel ways to exploit and unlock the potential of unconventional resources. These resources include tight gas reservoirs, tight sandstone oil, oil and gas shales reservoirs, and high pressure high temperature (HPHT) wells. Drilling of HPHT wells and shale reservoirs has become more widespread in the global petroleum and natural gas industry. There is a current need to extend robust techniques beyond costly drilling and completion jobs, with the potential for exponential expansion. Drilling fluids and their additives are being customized in order to cater for HPHT well drilling issues. Certain conventional additives, e.g., filtrate loss additives, viscosifier additives, shale inhibitor, and shale stabilizer additives are not suitable in the HPHT environment, where they are consequently inappropriate for shale drilling. A better understanding of the selection of drilling fluids and additives for hydrocarbon water-sensitive reservoirs within HPHT environments can be achieved by identifying the challenges in conventional drilling fluids technology and their replacement with eco-friendly, cheaper, and multi-functional valuable products. In this regard, several laboratory-scale literatures have reported that nanomaterial has improved the properties of drilling fluids in the HPHT environment. This review critically evaluates nanomaterial utilization for improvement of rheological properties, filtrate loss, viscosity, and clay- and shale-inhibition at increasing temperature and pressures during the exploitation of hydrocarbons. The performance and potential of nanomaterials, which influence the nature of drilling fluid and its multi-benefits, is rarely reviewed in technical literature of water-based drilling fluid systems. Moreover, this review presented case studies of two HPHT fields and one HPHT basin, and compared their drilling fluid program for optimum selection of drilling fluid in HPHT environment.
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Lin, Siyuan, Yunhu Lu, Zhiqin Liu, Wei Lu, and Po Hu. "Novel Water-Based Mud for Low-Permeable Reservoir in South China Sea." Energies 16, no. 4 (2023): 1738. http://dx.doi.org/10.3390/en16041738.
Full textAbstract:
Conventional reservoir drill-in fluids used for drilling reservoirs in Weizhou Oilfield encounter rheological problems that result in technical problems such as hole-cleaning in openhole horizontal intervals. Hence, novel drill-in fluid was developed by optimizing the additive quantity and particle size distribution. Lab tests showed that novel drill-in fluids boast high low shearing rate viscosity, and provide promising cutting, carrying, and suspension capabilities. Furthermore, the novel drill-in fluids performed well in reservoir protection, with a permeability recovery rate of more than 90%. The novel drill-in fluids also have high inhibition capabilities with a linear expansion rate of mud shale as low as 10%, with a rolling recovery rate of up to 96.48%. Field application results showed no pipe-stuck was encountered during tripping in the horizontal interval when using the novel drill-in fluid. Moreover, by using the novel drill-in fluids, skin factor was reduced from 20.0 to −3.0, and daily oil production was double what was expected. It was concluded that novel drill-in fluids meets the demand of horizontal drilling intervals in Weizhou Oilfield and improves hole-cleaning and reservoir protection in the horizontal well.
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Basfar, Salem, Abdelmjeed Mohamed, Salaheldin Elkatatny, and Abdulaziz Al-Majed. "A Combined Barite–Ilmenite Weighting Material to Prevent Barite Sag in Water-Based Drilling Fluid." Materials 12, no. 12 (2019): 1945. http://dx.doi.org/10.3390/ma12121945.
Full textAbstract:
Barite sag is a serious problem encountered while drilling high-pressure/high-temperature (HPHT) wells. It occurs when barite particles separate from the base fluid leading to variations in drilling fluid density that may cause a serious well control issue. However, it occurs in vertical and inclined wells under both static and dynamic conditions. This study introduces a combined barite–ilmenite weighting material to prevent the barite sag problem in water-based drilling fluid. Different drilling fluid samples were prepared by adding different percentages of ilmenite (25, 50, and 75 wt.% from the total weight of the weighting agent) to the base drilling fluid (barite-weighted). Sag tendency of the drilling fluid samples was evaluated under static and dynamic conditions to determine the optimum concentration of ilmenite which was required to prevent the sag issue. A static sag test was conducted under both vertical and inclined conditions. The effect of adding ilmenite to the drilling fluid was evaluated by measuring fluid density and pH at room temperature, and rheological properties at 120 °F and 250 °F. Moreover, a filtration test was performed at 250 °F to study the impact of adding ilmenite on the drilling fluid filtration performance and sealing properties of the formed filter cake. The results of this study showed that adding ilmenite to barite-weighted drilling fluid increased fluid density and slightly reduced the pH within the acceptable pH range (9–11). Ilmenite maintained the rheology of the drilling fluid with a minimal drop in rheological properties due to the HPHT conditions, while a significant drop was observed for the base fluid (without ilmenite). Adding ilmenite to the base drilling fluid significantly reduced sag factor and 50 wt.% ilmenite was adequate to prevent solids sag in both dynamic and static conditions with sag factors of 0.33 and 0.51, respectively. Moreover, HPHT filtration results showed that adding ilmenite had no impact on filtration performance of the drilling fluid. The findings of this study show that the combined barite–ilmenite weighting material can be a good solution to prevent solids sag issues in water-based fluids; thus, drilling HPHT wells with such fluids would be safe and effective.
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Ospanov, Yerlan Kanatovich, and Gulzhan Abdullaevna Kudaikulova. "Synergistic Effects of Graphene Oxide and Nanocellulose on Water-Based Drilling Fluids: Improved Filtration and Shale Stabilization." Polymers 17, no. 7 (2025): 949. https://doi.org/10.3390/polym17070949.
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Shale formations pose significant challenges to traditional drilling fluids, including issues such as fluid invasion, cutting dispersion, and shale swelling, contributing to wellbore instability. While oil-based drilling fluids (OBM) effectively address these challenges, concerns over their environmental impact and cost limit their widespread adoption. Nanoparticles (NPs) have emerged as a promising frontier for enhancing the performance of water-based drilling fluids (WBDFs) in shale applications. This study examines the effectiveness of water-based drilling fluids (WBDFs) enhanced with a nanocomposite of graphene oxide (GO) and nanocellulose (NC) compared to that of conventional WBDFs. The combination of GO and NC is chosen for its synergistic effects: GO provides enhanced mechanical strength and barrier properties, while NC serves to stabilize the dispersion and improve the compatibility with WBDF matrices. The modification with NC aims to optimize the interaction between GO and the drilling fluid components, enhancing performance in regards to shale inhibition and fluid loss control. This research involved the successful synthesis and characterization of a GO/NC nanocomposite, which underwent examination through FTIR, PSD, and SEM analyses. We also evaluated the filtration properties of water-based drilling fluids (WBDF) enhanced with a graphene oxide/nanocellulose (GO/NC) nanocomposite and compared the results to those for conventional WBDF. Filtration performance was assessed under both low-temperature, low-pressure (LTLP) and high-temperature, high-pressure (HTHP) conditions, and contact angle measurements were conducted to examine the wettability of the shale. The results demonstrated that incorporating GO/NC into the WBDF reduced the filtrate volume by 17% under LTLP conditions and by 23.75% under HTHP conditions, indicating a significant improvement in filtration control. Furthermore, the GO/NC-WBDF increased the hydrophobicity of the shale, as shown by a 61° increase in the contact angle. These findings suggest that GO/NC enhances the performance of WBDF, particularly in unconventional shale formations, by reducing fluid loss and improving wellbore stability.
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Medved, Igor, Nediljka Gaurina-Međimurec, Karolina Novak Mavar, and Petar Mijić. "Waste Mandarin Peel as an Eco-Friendly Water-Based Drilling Fluid Additive." Energies 15, no. 7 (2022): 2591. http://dx.doi.org/10.3390/en15072591.
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Drilling fluid represents the most important fluid that must fulfill numerous important assignments during drilling operations. Many commercially available additives for water-based drilling fluid fall into the category of non-degradable and environmentally hazardous materials. Significant development in this area can be made by using biodegradable materials as additives in drilling fluids. The objective of this study was to determine whether mandarin peel powder particle size affects the properties of the drilling fluid. In this paper, mandarin peel was used in the form of a dry powder divided into particle sizes smaller than 0.1 mm, and between 0.1 mm and 0.16 mm. Mandarin peel powder was added to a water-based drilling fluid in four different concentrations (0.5, 1, 1.5, and 2% by volume of water). By increasing the mandarin peel powder concentration, the API filtration reduced up to 42%, PPT filtration significantly decreased up to 61.54%, while the rheological parameters generally increased but remained within acceptable limits. It is determined that the optimal concentration of mandarin peel powder is up to 1.5% by volume of water.
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Shen, Zhenzhen, Heng Zhang, Xingying Yu, et al. "Experimental Optimization of High-Temperature-Resistant and Low Oil—Water Ratio High-Density Oil-Based Drilling Fluid." Processes 11, no. 4 (2023): 1129. http://dx.doi.org/10.3390/pr11041129.
Full textAbstract:
Problems such as well loss and collapses in deep shale gas drilling are most often due to the development of cracks in the shale formation, resulting in significant leaks of drilling fluid, the sticking and burrowing of drilling tools, and other engineering accidents. In addition, the horizontal sections of wells are very long and issues of friction, rock transport, and formation contamination loom large. As a result, the performance of drilling fluids directly affects drilling efficiency, engineering accident rates, and reservoir protection effects. We first analyze the mechanisms of each emulsifier in an oil-based drilling fluid formulation and the filtration reduction mechanisms, taking into account the collapse-prone and abnormally high-pressure characteristics of shale formations. We undertake an experimental evaluation and optimization of polymeric surfactants, such as primary and secondary emulsions for high-performance oil-based drilling fluids. The design of rigid and deformable nano-micron plugging materials with a reasonable particle size range was achieved, and we obtained a low Oil—Water ratio and high-density oil-based drilling fluid system, with temperature resistance of 200 °C, an Oil—Water ratio as low as 70:30, compressive fracturing fluid pollution of 10%, and a maximum density of 2.6 g/cm3. The reuse rate reached 100%. The developed oil-based drilling fluid system with strong plugging, a high density, and a low Oil—Water ratio suitable for deep shale gas can effectively seal the well wall, reduce liquid invasion, prevent the wall from collapsing, reduce mud leakage, reduce the consumption of oil-based drilling fluid, improve the utilization rate of old mud, and reduce drilling costs.
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Ahmed, T.G., and N. Makwashi. "An Experimental Investigation of Temperature and Ageing Effects on Bentonite and Sepiolite Drilling Fluids." Nigerian Research Journal of Engineering and Environmental Sciences 6, no. 1 (2021): 432–41. https://doi.org/10.5281/zenodo.5048485.
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<em>The formulation of a suitable drilling fluid is necessary for the successful drilling of an oil and gas well. The rheological properties of drilling fluids vary with changes in conditions such as time and temperature. This makes it necessary to study the rheology of drilling fluids and how it is affected by these changes. As part of this work, experiments were carried out to investigate the density, rheological properties – plastic viscosity, yield point and gel strength and pH of bentonite and sepiolite water-based drilling fluid at different temperature and ageing conditions. In addition, the effect of xanthan gum commonly used as an additive in drilling fluid formulation was also investigated on the rheological properties of these muds. 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 plastic viscosity and yield point of sepiolite, bentonite and treated bentonite muds decreased with increase in ageing time and temperature while the gel strength increased with ageing time but also decreased with increase in temperature. Results from this work also indicated that plastic viscosity, yield point and gel strength increased as the concentration of xanthan gum increased, all of which decreased with increase in temperature. The beauty of these results is that it will enable mud engineers to appropriately understand the how these mud properties vary downhole where temperatures are relatively higher and how they vary over time</em><em>.</em>
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Gozalpour, Fathollah, Ali Danesh, Adrian Christopher Todd, and Bahman Tohidi. "Application of Tracers in Oil-Based Mud for Obtaining High-Quality Fluid Composition in Lean Gas/Condensate Reservoirs." SPE Reservoir Evaluation & Engineering 10, no. 01 (2007): 5–11. http://dx.doi.org/10.2118/94067-pa.
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Summary Oil-based drilling fluids are used extensively in drilling activities worldwide. During the drilling process, because of overbalance pressure in the mud column, the filtrate of oil-based mud invades the formation. This hydrocarbon-based filtrate mixes with the formation hydrocarbon, which can cause major difficulties in obtaining a representative reservoir-fluid sample. Despite the recent improvements in sampling, obtaining a contamination-free formation fluid is a major challenge, particularly in openhole wells. Depending on the type and conditions of the reservoir, the oil-based-mud filtrate is totally or partially miscible with the formation fluid. Oil-based-mud filtrate dissolves completely in reservoir oil; therefore, the captured sample contains the true reservoir oil with added filtrate. Gas condensate (lean gas condensate in particular) is often not fully miscible with mud filtrate. In this case, the mass exchange between gas condensate and mud filtrate makes the sample unrepresentative of the reservoir fluid. In this study, the impact of sample contamination with oil-based-mud filtrate on different types of reservoir fluids, including gas condensate and volatile-oil samples, is investigated. Two simple methods are suggested to retrieve the uncontaminated composition from a contaminated sample in which mud filtrate is totally dissolved in the formation fluid (i.e., reservoir-oil samples). A tracer-based technique is also developed to determine the composition of an uncontaminated reservoir-fluid sample from a sample contaminated with oil-based-mud filtrate, particularly for those cases in which the two fluids are partially miscible. The tracers are added to the drilling fluid, with the additional cost to the drilling-mud preparation being negligible. The capability of the developed techniques has been examined against deliberately contaminated reservoir-fluid samples under controlled conditions in the laboratory. The results indicate the reliability of the proposed methods. Introduction Historically, most drilling in the North Sea has used water-based muds; however, drilling certain formations with water-based muds can be difficult, primarily because of the hole instability caused by the swelling of water-absorbing rock. Problems of this type can be greatly alleviated by using mud suspended in an oil (rather than water) base. These oil-based muds also provide better lubrication and achieve significant increases in drilling progress (Davies et al. 1984). In recent years, oil-based drilling fluid has been used extensively in drilling activities in the North Sea. During the drilling process, because of overbalance pressure in the mud column, the mud filtrate invades the reservoir formation. Using an oil-based mud in the drilling, the mud filtrate can mix with the formation fluid. This can cause major difficulties in obtaining high-quality formation-fluid samples. Depending on the type and conditions of the reservoir, the mud filtrate can be totally or partially miscible with the formation fluid. This can alter the composition and phase behavior of the reservoir fluid significantly. Hence, the measured data using the collected formation-fluid samples need to be corrected for the contamination. In this study, contamination of different types of reservoir fluids with oil-based-mud filtrate, where the two fluids are partially or totally miscible, is discussed. Practical decontamination techniques are proposed to retrieve the original fluid composition from contaminated samples.