Minimizing the HTHP filtration loss of oil-based drilling fluid with swellable polymer microspheres

Zhong, Hanyi; Shen, Guangcheng; Qiu, Zhengsong; Lin, Yongxue; Fan, Lijun; Xing, Xiaodong; Li, Jia

doi:10.1016/j.petrol.2018.09.074

Cited by 64 publications

(19 citation statements)

References 19 publications

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“…The absorption peaks at 1643 cm À1 and 1400 cm À1 are assigned to C═O and C N stretching vibration of the amide group in SMN, the absorption peak at 3441 cm À1 represents the N H stretching band. 30,31 The presence of these typical absorption bands in the FTIR spectra indicates the occurrence of organic reactions of the fed monomers.…”

Section: Characteristics Of Rheology Modifiersmentioning

confidence: 99%

Lipophilic rheology modifier and its application in oil‐based drilling fluids

Zhou

2021

J of Applied Polymer Sci

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Control of rheological behavior plays an important role in the process of wellbore construction and ensure the success of drilling operation. This paper reports for the first time the use of poly-amide (SMN) and poly-ester (SMO) as potential rheology modifiers. Fourier transform infrared (FTIR) spectroscopy, nuclear magnetic resonance, and thermogravimetric analysis have been carried out to confirm the chemical structures and properties of SMN and SMO. The results from environmental scanning electron microscope (ESEM) illustrated that SMN and SMO are lamellar structures formed by the stacking or interpenetrating of thin sheets. The atomic force microscope test results show that the network structure is formed after dissolving rheology modifier in diesel oil. Combining with the rheology and suspension measurements, it can be determined that the addition of rheology modifier exhibited obvious influence on the viscosity, thixotropy, and settlement factor of W/O emulsion. The rheology control properties and suspension stability between two rheology modifiers and traditional rheology modifier organoclay were compared. After hot rolling at 180 C, the base mud containing organoclay exhibited excellent suspension stability, but the fluid had completely lost fluidity and consolidated into a block. For SMN and SMO addition into the base formula, the rheological parameters of base mud changed moderately and the settlement of barites was not observed after standing for 24 h.

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Section: Characteristics Of Rheology Modifiersmentioning

confidence: 99%

Lipophilic rheology modifier and its application in oil‐based drilling fluids

Zhou

2021

J of Applied Polymer Sci

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“…Material degradation: Many drilling fluid products are prone to thermal degradation at high temperature. While some drilling fluids may survive initially, in a long trip time under HPHT static conditions the drilling fluid properties can also deteriorate, vary drilling fluid density and causing fluid loss [94]. V.…”

Section: Hpht Drilling Fluid Challengesmentioning

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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“…As a rule, in such works [6,7], the effect of drilling fluid components with binding capacity is evaluated. Authors [8,9] consider water-swellable polymers primarily as water-reducing additives. They investigate properties of solid elastic additives to increase stability and stop loss of drilling mud.…”

Section: Introductionmentioning

confidence: 99%

Use of the water-swellable polymers (WSP) for wellbore stabilization in intensely fractured rock intervals

2021

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Current research on the stability of well walls when drilling in fractured rocks and also when drilling inclined sections of the well profile are based on the assessment of the effect of drilling fluid filtrate. The novelty of this work lies in studying the complex effect of a water-swellable polymer on the stability of well wall, on the one hand, and on the controlled loss of circulation on the other. For preparing rock samples, a method was used based on standard laboratory equipment fordrilling fluid properties. The well wall stability tests are performedon a direct shear apparatus.The WSP composition based on alcohol, ether, and surfactant (Polyecanol Flora) showed its efficiency by increasing the stability coefficient with the engagement of less and more internal friction angle.PHPA-based viscoelastic composition showed the best result by increasing the stability coefficient in the hazardous areas by 50-60%.

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Minimizing the HTHP filtration loss of oil-based drilling fluid with swellable polymer microspheres

Cited by 64 publications

References 19 publications

Lipophilic rheology modifier and its application in oil‐based drilling fluids

Lipophilic rheology modifier and its application in oil‐based drilling fluids

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

Use of the water-swellable polymers (WSP) for wellbore stabilization in intensely fractured rock intervals

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