Nanoscale Laponite as a Potential Shale Inhibitor in Water-Based Drilling Fluid for Stabilization of Wellbore Stability and Mechanism Study

Abstract The design features and the need to use a water-based solution make the task of ensuring trouble-free drilling of vertical wells non-trivial. This work is an example of an interdisciplinary approach to the analysis of the mechanisms of instability of the wellbore. Instability can be caused by a complex of reasons, in this case, standard geomechanical calculations are not enough to solve the problem. Engineering calculations and laboratory chemical studies are integrated into the process of geomechanical modeling. The recommendations developed in all three areas are interdependent and inseparable from each other. To achieve good results, it is necessary to comply with a set of measures at the same time. The key tasks of the project were: determination of drilling density, tripping the pipe conditions, parameters of the drilling fluid rheology, selection of a system for the best inhibition of clay swelling.

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Laponite: a promising nanomaterial to formulate high-performance water-based drilling fluids

Petroleum Science ◽

10.1007/s12182-020-00516-z ◽

2020 ◽

Author(s):

Xian-Bin Huang ◽

Jin-Sheng Sun ◽

Yi Huang ◽

Bang-Chuan Yan ◽

Xiao-Dong Dong ◽

...

Keyword(s):

High Performance ◽

Drilling Fluid ◽

Nitrogen Adsorption ◽

Drill String ◽

Wellbore Stability ◽

Fluid Loss ◽

Drilling Fluids ◽

Mechanism Analysis ◽

Water Based ◽

Inhibition Performance

Abstract High-performance water-based drilling fluids (HPWBFs) are essential to wellbore stability in shale gas exploration and development. Laponite is a synthetic hectorite clay composed of disk-shaped nanoparticles. This paper analyzed the application potential of laponite in HPWBFs by evaluating its shale inhibition, plugging and lubrication performances. Shale inhibition performance was studied by linear swelling test and shale recovery test. Plugging performance was analyzed by nitrogen adsorption experiment and scanning electron microscope (SEM) observation. Extreme pressure lubricity test was used to evaluate the lubrication property. Experimental results show that laponite has good shale inhibition property, which is better than commonly used shale inhibitors, such as polyamine and KCl. Laponite can effectively plug shale pores. It considerably decreases the surface area and pore volume of shale, and SEM results show that it can reduce the porosity of shale and form a seamless nanofilm. Laponite is beneficial to increase lubricating property of drilling fluid by enhancing the drill pipes/wellbore interface smoothness and isolating the direct contact between wellbore and drill string. Besides, laponite can reduce the fluid loss volume. According to mechanism analysis, the good performance of laponite nanoparticles is mainly attributed to the disk-like nanostructure and the charged surfaces.

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Experimental study on the influence of coal powders on the performance of water-based polymer drilling fluid

Energy Exploration & Exploitation ◽

10.1177/0144598720949977 ◽

2020 ◽

Vol 38 (5) ◽

pp. 1515-1534

Author(s):

Lei Zhang ◽

Xiaoming Wu ◽

Shuaifeng Lyu ◽

Penglei Shen ◽

Lulu Liu ◽

...

Keyword(s):

Surface Tension ◽

Contact Angle ◽

Coalbed Methane ◽

Drilling Fluid ◽

Wellbore Stability ◽

Filtration Loss ◽

Water Based ◽

Natural Degradation ◽

Tension Increase ◽

Powder Content

Coal powders, as cuttings, invade the drilling fluid along a coal seam during coalbed methane development, thereby changing the properties of the drilling fluid. Therefore, this work aims to investigate the influence of coal powders on drilling fluid performance. The powders of lignite, anthracite, and contrasting shale were added to a water-based polymer drilling fluid. Then, the rheology, filtration, lubricity, and adhesiveness were measured, and the natural degradation, as well as the wettability were further evaluated. The results show that some parameters of the drilling fluid, including viscosity, lubrication coefficient, adhesion coefficient, contact angle, and surface tension, increase after adding coal powders, while other parameters, such as filtration loss and natural degradation, decrease. Compared with lignite and shale, anthracite powders, with the lowest mineral content, exhibit the smallest change in the rheological property, lubricity, adhesion, and natural degradation of the drilling fluid. Moreover, the content and size of the coal powders generally have opposing effects on the drilling fluid. When the coal powder content reaches 3 wt.%, the surface tension and contact angle of the drilling fluid show more evident changes than other parameters. Based on the analysis of the stress intensity factor, the drilling fluid with coal powders exceeding 100 mesh can reduce the capillary force in microfractures, and in combination with other factors (such as reduced filtration loss and sealing and supporting of the microfractures), improves wellbore stability. Therefore, coal powders with suitable particle sizes and concentration levels are expected to become a new drilling fluid material to protect coal field reservoirs.

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Sodium Silicate Based Drilling Fluid Application in Gulf of Thailand to Stabilise Wellbore: A Case Study

10.2118/200991-ms ◽

2021 ◽

Author(s):

Waleepon Sukarasep ◽

Rahul Sukanta Dey ◽

Visarut Phonpuntin

Keyword(s):

Sodium Silicate ◽

High Performance ◽

Drilling Fluid ◽

Wellbore Stability ◽

Drilling Fluids ◽

Gulf Of Thailand ◽

Hole Cleaning ◽

Water Based ◽

Wellbore Strengthening ◽

Effective Seal

Abstract Sodium Silicate were first used in water-based drilling fluids to stabilize claystone formations in the 1930's, but found favour in the 1990's in high performance, non dispersed water based systems for drilling problematic claystone formations as an alternative to oil-based drilling fluids. In Bongkot South field, Gulf of Thailand, sodium silicate-based drilling fluid (SSBDF) were used with mixed success in shallow gas drilling. Typically, platform WP-33, the claystone formation of the 12¼" section were drilled with 5% v/v Sodium Silicate in the water based drilling fluid together with excessive circulation as intention to improve hole cleaning frequently result in a wellbore that was overgauge by upto 18.9% in some case. This led to further hole cleaning problem that also compromised cement job quality. A further 6 well campaign on WPS-16 required a re-evaulation of the SSBDF coupled to an understanding of the wellbore instability mechanisms that leads to hole enlargement. To overcome better wellbore stability, sodium silicate has been designed by increased concentration to 8% v/v sodium silicate treated drilling fluid showed optimal design for application base on application of SSBDF has been used on platform WP-11 in 2002. Rheology, hydraulic and flow regime was adjusted for laminar flow that reduced the erosion of fragile claystone formation in the wellbore. The revised SSBDF formulation at WPS-16 result in a significant reduction of hole enlargement to 3.2% in the claystone section through a combination of chemicals and mechanical inhibition that contribute improved hole cleaning. The addition of wellbore strengthening material also provide an effective seal to minimize gas invasion. This paper describes the field trials in the Gulf of Thailand drilled with revised sodium sodium silicate based drilling fluid, the use of wellbore strengthening materials to manage gas influxes, better drilling practice and hydraclic simulation concluded that high performance water based drilling fluid of this nature have wider application where oil-base drilling fluid have traditionally been used.

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Rheological Study of Nanosilica Based Drilling Fluid

Applied Mechanics and Materials ◽

10.4028/www.scientific.net/amm.575.128 ◽

2014 ◽

Vol 575 ◽

pp. 128-133 ◽

Cited By ~ 5

Author(s):

Nur Hashimah Alias ◽

Nuurhani Farhanah Mohd Tahir ◽

T.A.T. Mohd ◽

N.A. Ghazali ◽

E. Yahya ◽

...

Keyword(s):

Xanthan Gum ◽

Drilling Fluid ◽

Gel Strength ◽

Wellbore Stability ◽

Potential Candidate ◽

Drilling Mud ◽

Well Completion ◽

Strength Tests ◽

Water Based ◽

The Stability

In drilling and well completion operations, drilling fluid is a crucial element as it is employed for the purposes of several functions. The main functions of drilling fluid are to control formation pressure, maintain the wellbore stability, transport the cuttings up to surface to clean the borehole bottom as well as to lubricate and cool the drill bit. Moreover, it is used to minimize the drilling damage to reservoir and suspend cuttings when the pumping is stop, hence it will not falling back down the borehole. The purpose of this study is to formulate new drilling mud formulation modified with nanosilica. Six samples of water based mud (WBM) were prepared using three types of polymers, (Xanthan Gum, Hydro Zan Plus and Hydro Star HT), starch and nanosilica. Basic rheological tests such as density, viscosity and pH were carried out. The density test was carried out using mud balance meanwhile the pH test was using pH meter. Theplasticviscosity, yield point and gel strength tests were carried out using viscometer. Besides that, physical observation was also performed for as the stability test. The results concluded that water based mud incorporated with polymer Hydro Zan Plus and nanosilica can be a potential candidate to be commercialized as a smart nanodrilling fluid.

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The influence of water-based drilling fluid on mechanical property of shale and the wellbore stability

Petroleum ◽

10.1016/j.petlm.2015.12.002 ◽

2016 ◽

Vol 2 (1) ◽

pp. 61-66 ◽

Cited By ~ 16

Author(s):

Shu He ◽

Lixi Liang ◽

Yinjin Zeng ◽

Yi Ding ◽

Yongxue Lin ◽

...

Keyword(s):

Mechanical Property ◽

Drilling Fluid ◽

Wellbore Stability ◽

Water Based ◽

Influence Of Water

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Rheological Properties of Water Based Drilling Fluid in Deep Water Drilling Conditions

Applied Mechanics and Materials ◽

10.4028/www.scientific.net/amm.318.507 ◽

2013 ◽

Vol 318 ◽

pp. 507-512 ◽

Cited By ~ 1

Author(s):

Qian Sheng Yue ◽

Qing Zhi Yang ◽

Shu Jie Liu ◽

Bao Sheng He ◽

You Lin Hu

Keyword(s):

Low Temperature ◽

Rheological Property ◽

Deep Water ◽

Viscosity Ratio ◽

Drilling Fluid ◽

Wellbore Stability ◽

Water Soluble ◽

Water Medium ◽

Water Based ◽

Water Base

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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The Influence of SiO2 and TiO2 Nanoparticles on the Properties of Water-Based Mud

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

10.1115/omae2017-61276 ◽

2017 ◽

Cited By ~ 2

Author(s):

Petar Mijić ◽

Nediljka Gaurina-Međimurec ◽

Borivoje Pašić

Keyword(s):

Filter Cake ◽

Drilling Fluid ◽

Wellbore Stability ◽

Drilling Fluids ◽

Drilling Mud ◽

Shale Formations ◽

Wellbore Instability ◽

Water Based ◽

Fluid Properties

About 75% of all formations drilled worldwide are shale formations and 90% of all wellbore instability problems occur in shale formations. This increases the overall cost of drilling. Therefore, drilling through shale formations, which have nanosized pores with nanodarcy permeability still need better solutions since the additives used in the conventional drilling fluids are too large to plug them. One of the solutions to drilling problems can be adjusting drilling fluid properties by adding nanoparticles. Drilling mud with nanoparticles can physically plug nanosized pores in shale formations and thus reduce the shale permeability, which results in reducing the pressure transmission and improving wellbore stability. Furthermore, the drilling fluid with nanoparticles, creates a very thin, low permeability filter cake resulting in the reduction of the filtrate penetration into the shale. This thin filter cake implies high potential for reducing the differential pressure sticking. In addition, borehole problems such as too high drag and torque can be reduced by adding nanoparticles to drilling fluids. This paper presents the results of laboratory examination of the influence of commercially available nanoparticles of SiO2 (dry SiO2 and water-based dispersion of 30 wt% of silica), and TiO2 (water-based dispersion of 40 wt% of titania) in concentrations of 0.5 wt% and 1 wt% on the properties of water-based fluids. Special emphasis is put on the determination of lubricating properties of the water-based drilling fluids. Nanoparticles added to the base mud without any lubricant do not improve its lubricity performance, regardless of their concentrations and type. However, by adding 0.5 wt% SiO2-disp to the base mud with lubricant, its lubricity coefficient is reduced by 4.6%, and by adding 1 wt% TiO2-disp to the base mud with lubricant, its lubricity coefficient is reduced by 14.3%.

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Performance Evaluation of a Highly Inhibitive Water-Based Drilling Fluid for Ultralow Temperature Wells

Journal of Energy Resources Technology ◽

10.1115/1.4037712 ◽

2017 ◽

Vol 140 (1) ◽

Cited By ~ 16

Author(s):

Xin Zhao ◽

Zhengsong Qiu ◽

Mingliang Wang ◽

Weian Huang ◽

Shifeng Zhang

Keyword(s):

Drilling Fluid ◽

Hydrate Formation ◽

Wellbore Stability ◽

Drilling Fluids ◽

Offshore Drilling ◽

Ultralow Temperature ◽

Water Based ◽

Drilling Operations ◽

Inhibition Performance ◽

Static Conditions

Drilling fluid with proper rheology, strong shale, and hydrate inhibition performance is essential for drilling ultralow temperature (as low as −5 °C) wells in deepwater and permafrost. In this study, the performance of drilling fluids together with additives for ultralow temperature wells has been evaluated by conducting the hydrate inhibition tests, shale inhibition tests, ultralow temperature rheology, and filtration tests. Thereafter, the formulation for a highly inhibitive water-based drilling fluid has been developed. The results show that 20 wt % NaCl can give at least a 16-h safe period for drilling operations at −5 °C and 15 MPa. Polyalcohol can effectively retard pore pressure transmission and filtrate invasion by sealing the wellbore above the cloud point, while polyetheramine can strongly inhibit shale hydration. Therefore, a combination of polyalcohol and polyetheramine can be used as an excellent shale stabilizer. The drilling fluid can prevent hydrate formation under both stirring and static conditions. Further, it can inhibit the swelling, dispersion, and collapse of shale samples, thereby enhancing wellbore stability. It has better rheological properties than the typical water-based drilling fluids used in onshore and offshore drilling at −5 °C to 75 °C. In addition, it can maintain stable rheology after being contaminated by 10 wt % NaCl, 1 wt % CaCl2, and 5 wt % shale cuttings. The drilling fluid developed in this study is therefore expected to perform well in drilling ultralow temperature wells.

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