Salt-tolerant, Thermally-stable Rheology Modifier for Oilfield Drilling Applications

Wang, Jianzhao; Zheng, Jun; Musa, Osama M.; Farrar, David; Cockcroft, Bob; Robinson, Alison; Gibbison, Robert

doi:10.2118/141429-ms

Cited by 6 publications

(2 citation statements)

References 8 publications

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“…Wang et al [122] have suggested that an ideal viscosifier used for HPHT WBDF should possess similar rheological properties to xanthan gum, exhibiting high shear thinning properties with enhanced salt tolerance and thermal stability. For WBDF, a synthetic polymeric viscosifier has been developed which exhibits exceptional thickening efficiency, salt tolerance, and thermal stability at temperature ranges of 450-464 K in the presence of monovalent halide brines [123].…”

Section: Viscosifier Selection For Hpht Applicationmentioning

confidence: 99%

Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review

et al. 2020

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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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Section: Viscosifier Selection For Hpht Applicationmentioning

confidence: 99%

Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review

et al. 2020

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“…Due to their excellent water stability and ability to interact with oppositely charged macromolecules and surfaces, polyelectrolytes have been extensively used in various fields, from materials science and colloids to biophysics. Their predominant applications include usage in optoelectronic devices [ 14 ], solar cells [ 15 ], rheology modifiers [ 16 , 17 ], adsorbents [ 18 ], coatings [ 19 , 20 ], biomedical implants [ 21 ], colloidal stabilizers [ 22 ], suspending agents [ 23 ], and for drug delivery and pharmaceutical uses.…”

Section: Introductionmentioning

confidence: 99%

Polyelectrolyte–Dye Interactions: An Overview

Chakraborty

Bhattarai

2022

Polymers

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Polyelectrolytes are polymers with repeating units of ionizable groups coupled with counterions. Recently, polyelectrolytes have drawn significant attention as highly promising macromolecular materials with potential for applications in almost every sector of our daily lives. Dyes are another class of chemical compounds that can interact with substrates and subsequently impart color through the selective absorption of electromagnetic radiation in the visible range. This overview begins with an introduction to polyelectrolytes and dyes with their respective definitions, classifications (based on origin, molecular architecture, etc.), and applications in diverse fields. Thereafter, it explores the different possible interactions between polyelectrolytes and dyes, which is the main focus of this study. The various mechanisms involved in dye–polyelectrolyte interactions and the factors that influence them are also surveyed. Finally, these discussions are summarized, and their future perspectives are presented.

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Novel High Density Brine-Based Drill-In Fluids Significantly Increased Temperature Limit for HP/HT Applications

Zhou

Deville

Davis

2015

Day 1 Tue, March 17, 2015

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Drill-in fluids, also known as reservoir drilling fluids, are specifically designed to help minimize formation damage and facilitate wellbore cleanup. Typical water-based drill-in fluids use brines to achieve a desired fluid density and rely on acid-soluble solids, such as calcium carbonate, for bridging of pore spaces. Biopolymers, such as xanthan gum and crosslinked starch, are generally used as viscosifiers and fluid-loss additives for the drill-in fluids. Unfortunately, these biopolymers begin to degrade at temperatures greater than 275°F. As a result, conventional water-based drill-in fluids are generally limited to wells with temperatures below 300°F. Clay-free, brine-based drill-in fluids for temperatures greater than 300°F still pose challenges in high-pressure/high-temperature (HP/HT) conditions. Novel high density brine-based drill-in fluids have been developed using a specifically designed dual-functional polymer as a thermally stable viscosifier and fluid-loss additive. Divalent brines, such as CaBr2 (14.2 lbm/gal) and CaCl2 (11.6 lbm/gal), were used as the base fluids. The drill-in fluids show similar thixotropic behavior to those biopolymer-based, yet exhibit excellent thermal stability up to 450°F, which is at least 150°F higher than typical drill-in fluids. After static aging at 450°F for 16 hours, the fluids exhibited only slight color change, and no stratification or solid settling was observed. Rheological properties of the aged samples increased slightly compared to samples before aging. The samples still provided excellent fluid-loss control, even after aging, with a measured HP/HT fluid loss less than 10 mL after 30 minutes at 350°F. Core flow testing showed that the drill-in fluid is nondamaging after acid breaker treatment, with a return permeability of 100%.

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Salt-tolerant, Thermally-stable Rheology Modifier for Oilfield Drilling Applications

Cited by 6 publications

References 8 publications

Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review

Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review

Polyelectrolyte–Dye Interactions: An Overview

Novel High Density Brine-Based Drill-In Fluids Significantly Increased Temperature Limit for HP/HT Applications

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