Application of Benzotriazole Corrosion Inhibitor in Synthetic-Based Drilling Fluid and its Overall Impact in Improving Drilling Fluid Functionality

2021 ◽  
Author(s):  
Zhao Xionghu ◽  
Saviour Bassey Egwu ◽  
Deng Jingen ◽  
Miao Liujie
Keyword(s):  
Corrosion Rate ◽  
Corrosion Inhibitor ◽  
Coefficient Of Friction ◽  
Hot Rolling ◽  
Drilling Fluid ◽  
Effect Of Temperature ◽  
Fluid Loss ◽  
Fluid Composition ◽  
Fluid System ◽  
Before And After

Abstract The effect of corrosion inhibitor Benzotriazole on synthetic-based mud system was studied. Rheological performance of the benzotriazole enhanced synthetic-based fluid system was studied and compared against the base mud. To study its effect on dynamic wellbore conditions, different drilling fluid compositions were placed in a hot rolling oven for 16 hours at temperatures 150 °C and 170°C and the effect of temperature on mud properties were studied. Tests carried out include rheological test (before and after hot rolling), filtrate pH, lubricity test, and fluid loss test. The corrosion penetration rate was studied using the weight loss method. Based on experiment results, the synthetic-based mud system which comprised of benzotriazole displayed a reduction in coefficient of friction up to 95.93%. At ambient condition, optimal ratio of mineral oil:benzotriazole (M:B) which gives best lubricity performance on synthetic-based mud system is 80:20. This leads to improved corrosion inhibition and lubricity of the synthetic-based fluid by reducing the coefficient of friction up to 90.13%. Increased temperature led to further decrease in coefficient of friction with a % torque reduction of 95.93 displayed by the 80:20 ratio M:B mud composition at 170 °C. Significant alterations of the mud composition rheological and fluid loss parameters before and after exposure to high temperature in hot rolling oven were not observed. pH values were maintained ≥7 at the dynamic conditions highlighting solubility of the formulated fluid composition and absence of contaminants which can pose significant threats to the rates of corrosion in drill pipes. Increasing the concentration of Benzotriazole led to a reduction in corrosion rate. However, as the temperature effect increased, the corrosion rate elevated. Based on results from this investigation, it was concluded that Benzotriazole can be applied as a corrosion inhibitor in a synthetic-based drilling fluid system as an alternative corrosion inhibitor without significant alteration of the base mud properties. Benefits of this will be the optimization of extended reach well drilling operations due to excellent lubricity performance, corrosion rate reduction, compatibility with HPHT wellbore condition and fluid loss control.

scholarly journals Experimental Investigation of the Rheological Behavior of an Oil-Based Drilling Fluid with Rheology Modifier and Oil Wetter Additives

Molecules ◽  
2021 ◽  
Vol 26 (16) ◽  
pp. 4877
Author(s):  
Mobeen Murtaza ◽  
Sulaiman A. Alarifi ◽  
Muhammad Shahzad Kamal ◽  
Sagheer A. Onaizi ◽  
Mohammed Al-Ajmi ◽  
...  
Keyword(s):  
High Temperature ◽  
Zeta Potential ◽  
Hot Rolling ◽  
Emulsion Stability ◽  
Drilling Fluid ◽  
Temperature Tolerance ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Before And After ◽  
Rheology Modifier

Drilling issues such as shale hydration, high-temperature tolerance, torque and drag are often resolved by applying an appropriate drilling fluid formulation. Oil-based drilling fluid (OBDF) formulations are usually composed of emulsifiers, lime, brine, viscosifier, fluid loss controller and weighting agent. These additives sometimes outperform in extended exposure to high pressure high temperature (HPHT) conditions encountered in deep wells, resulting in weighting material segregation, high fluid loss, poor rheology and poor emulsion stability. In this study, two additives, oil wetter and rheology modifier were incorporated into the OBDF and their performance was investigated by conducting rheology, fluid loss, zeta potential and emulsion stability tests before and after hot rolling at 16 h and 32 h. Extending the hot rolling period beyond what is commonly used in this type of experiment is necessary to ensure the fluid’s stability. It was found that HPHT hot rolling affected the properties of drilling fluids by decreasing the rheology parameters and emulsion stability with the increase in the hot rolling time to 32 h. Also, the fluid loss additive’s performance degraded as rolling temperature and time increased. Adding oil wetter and rheology modifier additives resulted in a slight loss of rheological profile after 32 h and maintained flat rheology profile. The emulsion stability was slightly decreased and stayed close to the recommended value (400 V). The fluid loss was controlled by optimizing the concentration of fluid loss additive and oil wetter. The presence of oil wetter improved the carrying capacity of drilling fluids and prevented the barite sag problem. The zeta potential test confirmed that the oil wetter converted the surface of barite from water to oil and improved its dispersion in the oil.

scholarly journals Effect of Iron Oxide Nanoparticles on the Properties of Water-Based Drilling Fluids

Energies ◽  
2020 ◽  
Vol 13 (24) ◽  
pp. 6718
Author(s):  
Muhammad Awais Ashfaq Alvi ◽  
Mesfin Belayneh ◽  
Sulalit Bandyopadhyay ◽  
Mona Wetrhus Minde
Keyword(s):  
Iron Oxide ◽  
Coefficient Of Friction ◽  
Drilling Fluid ◽  
Precipitation Method ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
The Coefficient Of Friction ◽  
Filtrate Loss ◽  
Co Precipitation ◽  
The Impact

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.

scholarly journals Evaluation of environment friendly micro-ionized litchi leaves powder (LLP) as a fluid loss control agent in water-based drilling fluid

2021 ◽  
Vol 11 (4) ◽  
pp. 1715-1726
Author(s):  
Ved Prakash ◽  
Neetu Sharma ◽  
Munmun Bhattacharya ◽  
Ashok Raina ◽  
Man Mohan Gusain ◽  
...  
Keyword(s):  
Hot Rolling ◽  
Drilling Fluid ◽  
Control Agent ◽  
American Petroleum Institute ◽  
Rheological Parameters ◽  
Fluid Loss ◽  
Environment Friendly ◽  
Filtration Loss ◽  
Water Based ◽  
Loss Control

AbstractThis work investigates the efficacy of a biodegradable natural product, litchi leaves powder (LLP) as a filtration loss control agent in the water-based drilling fluid formulations. In order to evaluate the potential of litchi leaves powder (LLP), a strict protocol of experimentations according to API (American Petroleum Institute) standard has been followed. The experimental outcome showed that before hot rolling and after hot rolling of mud samples at 100 °C it was observed that 3–5% Concentration of LLP significantly increased the rheological parameters such as PV, YP and gelation of drilling fluid as compared to reference mud. Also, LLP reformed the filtration loss control characterization, suggesting a better biodegradable fluid loss reducing agent. After hot rolling at 100 °C for 18 h, the water-based drilling fluid with LLP as an additive showed a marked reduction in filtration control property as compared to reference Mud (RM). Experimental results concluded that 5% concentration of LLP significantly reduced the filtration loss of drilling fluid by 70.6% as compared to reference mud under the influence of 100 psi pressure. However, the conventional fluid loss additive CMC (LVG) reduced the filtration loss by maximum 67.5% as compared to reference mud. Therefore, LLP can be used as an alternative to CMC (LVG) in water-based drilling fluid with a maximum subsurface temperature of 100 °C.

scholarly journals EFFECT OF TEMPERATURE AND CONCENTRATION OF NaOH SOLUTIONS AS INHIBITORS ON IRON CORROSION RATE IN WATER MEDIA

Konversi ◽  
2020 ◽  
Vol 9 (1) ◽  
Author(s):  
Muthia Elma ◽  
Nurhalisah Nurhalisah ◽  
Afrisa Noor Hidayanti
Keyword(s):  
Corrosion Rate ◽  
Corrosion Inhibitors ◽  
Protective Layer ◽  
Effect Of Temperature ◽  
Iron Corrosion ◽  
Before And After ◽  
Water Media ◽  
Naoh Solution ◽  
Increasing Temperature ◽  
Area And Volume

Corrosion is a chemical phenomenon that often occurs in iron materials that are exposed or immersed in a medium either liquid or air. As a result of this corrosion is fragility and damage to the object so that the object cannot function properly. The purpose of this research is to prevent or slow down the occurrence of corrosion by adding chemicals called corrosion inhibitors which work by forming a protective layer on the surface of objects in the form of metal or iron.In this study, inhibitors were used in the form of NaOH solution with variations in the concentration of 0.1; 0.5; 1; 1.25; 1,5; 5 and 10 N are dissolved in water media and the iron immersion process is carried out at temperatures of 40, 45, and 50 °C. Soaked iron bars are measured for surface area and volume as well as weighing before and after the immersion process so that the corrosion rate is obtained with various variables used. Based on the research results obtained corrosion rate increases with increasing temperature and the addition of NaOH concentration inhibitors. Optimal temperature and concentration to inhibit the rate of iron corrosion is at an immersion temperature of 45 ° C and a concentration of 0.1 N NaOH with a corrosion rate of 0.084875 mpy.

Study of Drilling Fluid System of Resisting the High Temperature of 220 Degrees

2013 ◽  
Vol 753-755 ◽  
pp. 130-133
Author(s):  
Hui Hong Luo ◽  
Ze Hua Wang ◽  
Yu Xue Sun ◽  
Han Jiang
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Fluid Loss ◽  
Borehole Stability ◽  
Fluid System ◽  
Well Drilling ◽  
Deep Well ◽  
Materials Used ◽  
Loss Control ◽  
Determine System

Focus on the high temperature rheological stability and the fluid loss control of resistance to high temperature drilling fluid system, further determine system formula and the formula of the high temperature drilling fluid system should be optimized. Eventually, a kind of organo-silica drilling fluid system of excellent performance which is resistant to high temperature of 220 degrees has been developed, and the system performances have been evaluated. The high temperature-resistant organo-silica drilling fluid system is of good shale inhibition, lubricity and borehole stability. The fluid loss is low and the filter cake is thin and tight, which can effectively prevent bit balling. The sand-carrying ability is good and the rheological property is easy to control. The performances of drilling fluid remain stable under high salinity and the system can resist the pollution of 6%NaCl and 0.5%CaC12. The materials used in this system are non-toxic, non-fluorescent and suitable for deep well drilling.

scholarly journals Influence of Graphene Nanoplatelet and Silver Nanoparticle on the Rheological Properties of WaterBased Mud †

2018 ◽  
Vol 8 (8) ◽  
pp. 1386 ◽  
Author(s):  
Hazlina Husin ◽  
Khaled Abdalla Elraies ◽  
Hyoung Jin Choi ◽  
Zachary Aman
Keyword(s):  
Rheological Properties ◽  
Silver Nanoparticle ◽  
Drilling Fluid ◽  
Oil Field ◽  
Fluid Loss ◽  
Drilling Mud ◽  
Fluid System ◽  
Graphene Nanoplatelet ◽  
Environmental Friendly ◽  
Water Based

Water-based mud is known as an environmental-friendly drilling fluid system. The formulation of water-based mud is designed to have specific rheological properties under specific oil field conditions. In this study, graphene nanoplatelet and silver nanoparticle (nanosilver) were added to a water-based mud formulation in which they act as drilling mud additives. Rheological properties measurements and filtration tests were conducted for evaluating the influence of the added nanoparticles. The results showed that the graphene nanoplatelet and the nanosilver increased the plastic viscosity (PV) by up to 89.2% and 64.2%, respectively. Meanwhile, both the yield point (YP) and the fluid loss values were reduced. In addition, we believe this is the first result ever report where nanosilver is utilized for enhancing-enhanced water-based mud’s performance.

Incorporation of Fe3O4 Nanoparticles as Drilling Fluid Additives for Improved Drilling Operations

2016 ◽  
Author(s):  
Zisis Vryzas ◽  
Omar Mahmoud ◽  
Hisham Nasr-El-Din ◽  
Vassilis Zaspalis ◽  
Vassilios C. Kelessidis
Keyword(s):  
Electron Microscope ◽  
Rheological Properties ◽  
Fe3o4 Nanoparticles ◽  
Filter Cake ◽  
Drilling Fluid ◽  
Filter Press ◽  
Rheological Parameters ◽  
Fluid Loss ◽  
Fluid System ◽  
Custom Made

A successful drilling operation requires an effective drilling fluid system. Due to the variety of downhole conditions across the globe, the fluid system should be designed to meet complex challenges such as High-Pressure/High-Temperature (HPHT) environments, while promoting better productivity with a minimum interference for completion operations. This study aims to improve the rheological and fluid loss properties of water-bentonite suspensions by using both commercial (C-NP) and custom-made (CM-NP) iron oxide (Fe3O4) nanoparticles (NP) as drilling fluid additives. Superparamagnetic Fe3O4 NP were synthesized by the co-precipitation method. Both types of nanoparticles were characterized by a High Resolution Transmission Electron Microscope (TEM) and X-ray Diffraction (XRD). Base fluid (BF), made of deionized water and bentonite at 7wt%, was prepared according to American Petroleum Institute (API) procedures and nanoparticles were added at 0.5wt%. A Couette-type viscometer was used to analyze the rheological characteristics of these fluids at different shear rates and various temperatures (up to 158°F). The rheological parameters were obtained from analysis of viscometric data using non-linear regression. The API Low-Pressure/Low-Temperature (LPLT) and HPHT fluid filtrate volumes were measured, using a standard API LPLT static filter press (100 psi, 77°F) and an API HPHT filter press (300 psi, 250°F). Observation of the porous matrix morphology of the produced filter cakes was done with Scanning Electron Microscope (SEM). TEM showed that the mean diameter of the CM-NP was 7–8 nm, with measured surface areas between 100–250 m2/g. The C-NP had an average diameter of <50 nm, as per manufacturer specifications. The XRD of the CM-NP revealed peaks corresponding to pure crystallites of magnetite (Fe3O4) with no impurities. Rheological analysis showed very good fitting by the Herschel-Bulkley model with coefficient of determination (R2) greater than 0.99. Rheological properties of all samples were affected by higher temperatures, with increase in yield stress, decrease in flow consistency index (K) and slight increase in flow behavior index (n). Fluid filtration results indicated a decrease in the LPLT fluid loss and an increase in the filter cake thickness compared to the BF upon addition of higher concentrations of C-NP, because of a decrease in filter cake permeability. At HPHT conditions, samples with 0.5wt% C-NP had a smaller fluid loss by 34.3%, compared to 11.9% at LPLT conditions. CM-NP exhibited even higher reduction in the fluid loss at HPHT conditions of 40%. Such drilling fluids can solve difficult drilling problems and aid in achieving the reservoir’s highest potential by eliminating the use of aggressive, potentially damaging chemicals. Exploitation of the synergistic interaction of the utilized components can produce a water-based system with excellent fluid loss characteristics while maintaining optimal rheological properties.

Properties of high temperature resistance and salt tolerance drilling fluids incorporating acrylamide/2-acrylamido-2-methyl-1-propane sulfonic acid/N-vinylpyrrolidone/dimethyl diallyl ammonium chloride quadripolymer as fluid loss additives

2014 ◽  
Vol 34 (2) ◽  
pp. 153-159 ◽  
Author(s):  
Junlin Su ◽  
Qi Chu ◽  
Mao Ren
Keyword(s):  
High Temperature ◽  
Ammonium Chloride ◽  
Thermal Aging ◽  
Sulfonic Acid ◽  
Drilling Fluid ◽  
Gel Permeation Chromatography ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Aging Test ◽  
Before And After

Abstract A quadripolymer of acrylamide (AM), 2-acrylamido-2-methyl-1-propane sulfonic acid (AMPS), N-vinylpyrrolidone (NVP) and dimethyl diallyl ammonium chloride (DMDAAC) was synthesized by solution free radical polymerization, and characterized using Fourier transform infrared (FTIR), gel permeation chromatography (GPC) and thermogravimetric analysis (TGA) methods. The rheological and filtrate properties of saturated brine-based fluid with AM/AMPS/NVP/DMDAAC quadripolymer were investigated before and after thermal aging tests. The apparent viscosity (AV), plastic viscosity (PV) and yield point (YP) increased and the filtrate volume decreased with increase in the concentration of AM/AMPS/NVP/DMDAAC quadripolymer after thermal aging test at 180°C for 16 h. The filtrate volume could be controlled when the concentration of AM/AMPS/NVP/DMDAAC quadripolymer reached 2.0% under these conditions. The filtrate volume of saturated brine-based fluid could be controlled effectively at a thermal aging temperature not exceeding 200°C and was smaller than that of the AM/AMPS/NVP terpolymer. The AM/AMPS/NVP/DMDAAC quadripolymer was better at improving the quality of a filter cake than the AM/AMPS/NVP terpolymer. The drilling fluid containing the AM/AMPS/NVP/DMDAAC quadripolymer had an excellent tolerance to salt and high temperature.

The Application Of Methyl Glucoside As Shale Inhibitor In Sodium Chloride Mud

2012 ◽  
Author(s):  
Issham Ismail ◽  
Poon Huang Ann
Keyword(s):  
Sodium Chloride ◽  
Hot Rolling ◽  
Drilling Fluid ◽  
Clay Content ◽  
Control Agent ◽  
American Petroleum Institute ◽  
Fluid Loss ◽  
Methyl Glucoside ◽  
Water Based ◽  
Dispersion Test

Lumpur metil glukosida, atau dikenali sebagai MEG, ialah lumpur dasar air terkini yang mesra alam. Lumpur ini mempunyai prestasi yang hampir menyamai lumpur dasar minyak. Projek ini dilaksanakan bagi mengkaji kesan penambahan MEG ke dalam lumpur natrium klorida (MEG/NaCl) untuk mengawal pengembangan dan penyerakan syal pada beberapa kepekatan yang berlainan, iaitu 5% hingga 35% berdasarkan berat. Kajian ini melibatkan ujian penyerakan putaran panas yang berdasarkan American Petroleum Institute – Recommended Practice – 13I. Sifat pengawalan sedemikian turut dikaji menggunakan beberapa sampel syal yang mempunyai kereaktifan dan kandungan lempung yang berlainan. Selain itu, prestasi lumpur MEG/NaCl turut dikaji menerusi ujian sifat reologi, kawalan kehilangan turasan, aktiviti air dalam lumpur, dan proses penuaan, sebagaimana yang dicadangkan dalam American Petroleum Institute – Recommended Practice – 13B. Kajian menunjukkan bahawa lumpur MEG/NaCl boleh mengurangkan masalah pengembangan dan penyerakan syal. Namun begitu, kepekatan yang berkesan adalah bergantung kepada kereaktifan dan kandungan lempung yang wujud dalam sampel syal. Hasil kajian juga menunjukkan bahawa MEG ialah agen kawalan kehilangan bendalir yang baik. Kata kunci: Ujian penyerakan putarasan panas; metil glukosida (MEG); penyerakan syal; pengembangan syal; lumpur dasar air The methyl glucoside drilling fluid, or designated as the MEG, is a recently developed environmentally–friendly water–based mud. It is said to possess performance that approaches the oil–based mud. This project studied on the effects of introducing MEG into sodium chloride (MEG/NaCl) mud in controlling shale hydration and dispersion at different concentrations, namely 5% to 35% by weight, through hot rolling dispersion test, based on the American Petroleum Institute – Recommended Practice – 13I. The inhibitive features were further evaluated against several shale samples which had different reactivity and clay contents. Besides, the performance of MEG/NaCl mud was also evaluated through series of rheological properties, fluid loss, mud water activity, and ageing process tests as recommended in the American Petroleum Institute – Recommended Practice – 13B. The experimental results revealed that MEG/NaCl mud system could satisfactorily exhibit shale stabilization performance. The effective concentration of MEG, however, was corresponding on the reactivity and clay content present in the shale. The experiment results also showed that MEG is a good fluid loss control agent. Key words: Hot rolling dispersion test; methyl glucoside (MEG); shale dispersion; shale swelling; water–based mud

Experimental Investigation of Aloe-Vera-Based CuO Nanofluid as a Novel Additive in Improving the Rheological and Filtration Properties of Water-Based Drilling Fluid

2021 ◽  
pp. 1-10
Author(s):  
Hameed Hussain Ahmed Mansoor ◽  
Srinivasa Reddy Devarapu ◽  
Robello Samuel ◽  
Tushar Sharma ◽  
Swaminathan Ponmani
Keyword(s):  
Thermal Stability ◽  
Hot Rolling ◽  
Drilling Fluid ◽  
Aloe Vera ◽  
Petroleum Engineering ◽  
Fluid Loss ◽  
Water Based ◽  
Drilling Operations ◽  
Filtration Properties ◽  
The Impact

Summary Drilling technology in petroleum engineering is associated with problems such as high fluid loss, poor hole cleaning, and pipe sticking. Improvement of rheological and filtration properties of water-based drilling fluids (WDFs) plays a major role in resolving these drilling problems. The application of nanotechnology to WDF in the recent past has attracted much attention in addressing these drilling operations problems. In the present work, we investigate the application of natural aloe vera and CuO nanofluids combined as an additive in WDF to address the drilling problems. The nanofluids of three different concentrations of CuO nanoparticle (0.2, 0.4 , and 0.6 wt%) with aloe vera as a base fluid are prepared for this study by adopting a two-step method. The prepared nanofluids are characterized by their particle size and morphological characteristics. Conventional WDF (DF.0) is synthesized, and the prepared aloe-vera-based CuO nanofluid is added to the WDF to prepare nanofluid-enhancedwater-based drilling fluid (NFWDF) of different concentrations of nanoparticles, namely, 0.2 , 0.4, and 0.6 wt%. The prepared drilling fluid mixture is then characterized for its rheological and filtrate loss properties at various temperatures. Thermal stability and aging studies are performed for both WDF and NFWDF. The experimental results are then modeled using rheological models. The results reveal that aloe-vera-based CuO nanofluids improve the thermal stability and rheological properties of drilling fluid and significantly decrease the American Petroleum Institute (API) filtrate. Viscosity for WDF shows an approximately 61.7% decrease in heating up to 90°C. Further, the hot roll aging test causes a 63% decrease in the viscosity of WDF at 90°C. However, the addition of aloe-vera-based CuO nanofluids is found to aid in recovering the viscosities to a great extent. The fluid loss values before hot rolling are observed to be 6.6 mL after 30 minutes, whereas fluid loss values for the NFWDFs are found to be 5.9, 5.4, and 4.6 mL, respectively. The fluid loss value after hot rolling for the WDF is found to be 10.8 mL after 30 minutes, whereas fluid loss values for the NFWDFs are found to be 9.2, 8.5, and 7.7 mL, respectively. The rheological performance data of NFWDF project a better fit with the Herschel-Bulkley model and suggest improvement in rheological and filtration properties. There has been limited research work available in understanding the impact of aloe-vera-gel-based nanofluids in improving the performance of WDFs through the improvement of its rheological and filtration properties. This study aims to exploit the property of native aloe vera and CuO nanofluids combined together to enhance the rheological and filtration properties of WDF by conducting the tests both before and after hot rolling conditions. This study acts as an important precursor for developing novel additives for WDF to improve its rheological and filtration properties. This study is also expected to benefit the industry and solve the major challenges in deep-well drilling operations and high-pressure and high-temperature (HPHT) drilling operations.

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