A state of the art review on the performance of high-pressure and high-temperature drilling fluids: Towards understanding the structure-property relationship of drilling fluid additives

Gautam, Sidharth; Guria, Chandan; Rajak, Vinay Kumar

doi:10.1016/j.petrol.2022.110318

Cited by 82 publications

(37 citation statements)

References 199 publications

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“…Fluid loss reducer, as one of the most essential additives in WBDFs, which can fully control the rheology and filtration performance of drilling fluids, has attracted extensive attention from petroleum engineering researchers in academia and industry [ 9 , 10 , 11 , 12 ]. The common fluid loss reducers are mainly divided into two categories: natural/natural-modified polymers and synthetic polymers, which can optimize the particle size distribution of bentonite particles and reduce the permeability of mud cakes, thereby achieving the effect of reducing drilling fluid filtration [ 13 ]. Natural fluid loss additives, including humic acid, cellulose, lignin, starch, phenolic resin, etc., have been widely used in conventional formation drilling operations due to their vast sources and lack of environmental harm [ 14 , 15 , 16 , 17 , 18 , 19 , 20 ].…”

Section: Introductionmentioning

confidence: 99%

Nano-Modified Polymer Gels as Temperature- and Salt-Resistant Fluid-Loss Additive for Water-Based Drilling Fluids

Sun

et al. 2022

Gels

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With the continuous exploration and development of oil and gas resources to deep formations, the key treatment agents of water-based drilling fluids face severe challenges from high temperatures and salinity, and the development of high temperature and salt resistance filtration reducers has always been the focus of research in the field of oilfield chemistry. In this study, a nano-silica-modified co-polymer (NS-ANAD) gel was synthesized by using acrylamide, isopropylacrylamide, 2-acrylamide-2-methyl propane sulfonic acid, diallyl dimethyl ammonium chloride, and double-bond-modified inorganic silica particles (KH570-SiO2) through free radical co-polymerization. The introduction of nanotechnology enhances the polymer’s resistance to high temperature degradation, making it useful as a high-temperature-resistant fluid loss reducer. Moreover, the anions (sulfonates) and cations (quaternary ammonium) enhance the extension of the polymer and the adsorption on the surface of bentonite particles in a saline environment, which in turn improves the salt resistance of the polymer. The drilling fluids containing 2.0 wt% NS-ANAD co-polymer gels still show excellent rheological and filtration performance, even after aging in high temperature (200 °C) and high salinity (saturated salt) environments, showing great potential for application in deep and ultra-deep drilling engineering.

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Section: Introductionmentioning

confidence: 99%

Nano-Modified Polymer Gels as Temperature- and Salt-Resistant Fluid-Loss Additive for Water-Based Drilling Fluids

Sun

et al. 2022

Gels

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“…Traditional polymer tackifiers (such as carboxymethyl cellulose and hydroxyethyl cellulose) cannot meet the temperature-and salt resistance required for solids-free drilling fluids. 6 In addition, these polymer additives are poorly degradable and significantly pollute reservoirs. Therefore, it is imperative to develop a reservoir-friendly viscosifier for solids-free drilling fluids.…”

Section: Introductionmentioning

confidence: 99%

Preparation of a salt‐responsive Gemini viscoelastic surfactant for application to solids‐free drilling fluids

Deng

Sun

Ren

et al. 2022

J of Applied Polymer Sci

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In order to solve the problem of poor rheological properties of solid‐free drilling fluids in salt‐bearing formations and prevent drilling accidents such as lost circulation, formation collapse, and wellbore instability, it is crucial to develop a new type of viscosifier. In this study, a salt‐responsive Gemini viscoelastic surfactant (NT‐1) was synthesized by using erucamide as a hydrophobic chain and introducing a benzene ring and a carboxyl group into the linker. In addition, it is used as a viscosifier for solid‐free drilling fluids. The structure of the surfactant was characterized by 1H nuclear magnetic resonance (NMR), 13C NMR, Fourier transform infrared spectroscopy, and electrospray ionization tandem mass spectrometry (ESI‐MS), and its physicochemical properties were determined by surface tensiometer, thermogravimetric‐differential scanning calorimetry, dynamic lighting scattering and rheometer. Its performance in solid‐free drilling fluids was evaluated according to the American Petroleum Institute (API) standard. The results show that the surfactant has a low critical micelle concentration (31.74 μmol/L), excellent thermal stability and water solubility. In particular, NT‐1 can self‐assemble into worm‐like micelles under the action of salt, and the spatial network structure formed by the interweaving of these micelles can endow the drilling fluid with good rheology and viscoelasticity. NT‐1 is compatible with conventional drilling fluid polymer additives, which can effectively improve solid‐free drilling fluids' rheological properties and fluid loss properties in salt layers. The temperature resistance in drilling fluid systems can reach 120°C. This work verifies the feasibility of using viscoelastic surfactants as viscosifiers in solid‐free drilling fluids and provides new ideas for developing salt‐responsive smart drilling fluids.

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“…In recent years, complex deep wells have become the main exploration frontier in the world . With the drilling operation advancing to deeper oil and gas wells, developing high-temperature and high-pressure (HTHP) drilling fluid has become a trend. , Under differential pressure, the fluid in the drilling fluid will penetrate the surrounding formation of the well wall. At this time, the solid particles and polymers in the drilling fluid will be filtered out and form mud cake on the well wall (Figure a). − The mud cake is beneficial for drilling because it will reduce fluid loss and ensure wellbore stability. − However, the interface between the formation and cement sheath is critical to the integrity and environmental protection of oil and gas wells .…”

Section: Introductionmentioning

confidence: 99%

“… 1 With the drilling operation advancing to deeper oil and gas wells, developing high-temperature and high-pressure (HTHP) drilling fluid has become a trend. 2 , 3 Under differential pressure, the fluid in the drilling fluid will penetrate the surrounding formation of the well wall. At this time, the solid particles and polymers in the drilling fluid will be filtered out and form mud cake on the well wall ( Figure 1 a).…”

Section: Introductionmentioning

confidence: 99%

Novel Evaluation Method for Flushing Efficiency Based on the Principle of Wall Shear Rate Equality under High Temperature and High Pressure

Yuan

Yang

et al. 2022

ACS Omega

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An excellent flushing efficiency evaluation device is indispensable for studying the cementing flushing fluid. However, the existing flushing efficiency evaluation device cannot simulate the formation and flushing process of the downhole mud cake. Therefore, this paper proposes a novel flushing efficiency evaluation device that can simulate the formation and flushing of downhole mud cakes. The rotational speed of the device during flushing and the rotor’s diameter is deduced based on the principle of equal wall shear rate. The evaluation device and method can be used to quantitatively evaluate the flushing efficiency of the flushing liquid on the mud cake under high temperatures and high pressures. This device analyzed the effects of the annular gap, temperature, construction displacement, and flushing fluids on flushing efficiency. The results show that the smaller the annular gap, the higher the temperature, the larger the displacement, the higher the scouring efficiency, and the higher the shear bond strength. Fiber flushing has the dual function of mechanical and chemical flushing, so its flushing efficiency is 14.75% higher than that of heavy flushing fluid at 10 min. The surfactant in the emulsified rinse leads to a sudden increase in rinse efficiency in the middle and late stages. The reduced flushing efficiency of the flushing fluid is due to the reduced ζ potential.

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A state of the art review on the performance of high-pressure and high-temperature drilling fluids: Towards understanding the structure-property relationship of drilling fluid additives

Cited by 82 publications

References 199 publications

Nano-Modified Polymer Gels as Temperature- and Salt-Resistant Fluid-Loss Additive for Water-Based Drilling Fluids

Nano-Modified Polymer Gels as Temperature- and Salt-Resistant Fluid-Loss Additive for Water-Based Drilling Fluids

Preparation of a salt‐responsive Gemini viscoelastic surfactant for application to solids‐free drilling fluids

Novel Evaluation Method for Flushing Efficiency Based on the Principle of Wall Shear Rate Equality under High Temperature and High Pressure

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