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J. Desbrieres - One of the best experts on this subject based on the ideXlab platform.
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cement cake properties in static filtration influence of polymeric additives on cement filter cake permeability
Cement and Concrete Research, 1993Co-Authors: J. DesbrieresAbstract:During cementing operations on oil wells, Fluid Loss Control additives are generally used to prevent water Loss and to maintain a constant water-to-solid ratio in cement slurries. But their mechanism of action is not yet completely understood. An experimental procedure is described to discriminate between the two predominant phenomena which are the increase of interstitial water viscosity and the decrease of cement cake permeability. The influence of polymeric additives is studied and more particularly the efficiency of Fluid Loss Control additives is related with a threshold concentration corresponding to the overlapping concentration of macromolecular chains in solution.
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Cement cake properties in static filtration. On the role of Fluid Loss Control additives on the cake porosity
Cement and Concrete Research, 1993Co-Authors: J. DesbrieresAbstract:The mechanism of the action of Fluid Loss Control additives in cementing oilwell operations is principally the reduction of permeability of the cement filter cake. From filtration equations physical characteristics as porosity of the cement filter cake were investigated and compared with experimental data. A good correlation is observed when no adsorption is involved. The smallest pore diameter for obtaining an efficient Control of Fluid Loss is shown to be of the same order of magnitude as the gyration radius of used macromolecular chains. © 1993.
Johann Plank - One of the best experts on this subject based on the ideXlab platform.
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role of colloidal polymer associates for the effectiveness of hydroxyethyl cellulose as a Fluid Loss Control additive in oil well cement
Journal of Applied Polymer Science, 2012Co-Authors: Daniel Bulichen, Johann PlankAbstract:The working mechanism of hydroxyethyl cellulose (HEC) as a Fluid Loss additive in oil well cement was investigated. The specific anionic charge amount, intrinsic viscosity, and associative behavior in a cement pore solution were determined. The Fluid Loss performance was probed through the static filtration of cement slurries. HEC achieves Fluid Loss Control by reducing cement filtercake permeability. No influence on the filtercake microstructure was observed. ζ Potential measurements and a special filtration test indicated that no adsorption on cement occurred. Environmental scanning electron microscopy images revealed that in a wet environment, HEC swelled to a multiple of its size and possessed an enormous water-sorption capacity. Concentration-dependent measurements of the hydrodynamic diameter of HEC dissolved in a cement pore solution showed that large associates were formed. These colloidal associates physically obstructed the filtercake pores. Finally, the addition of sulfonated melamine formaldehyde dispersant to the cement slurries containing HEC greatly improved the Fluid Loss Control. A specific interaction was responsible for this synergistic effect. © 2012 Wiley Periodicals, Inc. J Appl Polym Sci, 2012
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mechanistic study on carboxymethyl hydroxyethyl cellulose as Fluid Loss Control additive in oil well cement
Journal of Applied Polymer Science, 2012Co-Authors: Daniel Bulichen, Johann PlankAbstract:The working mechanism of carboxymethyl hydroxyethyl cellulose (CMHEC, Mw 2.6 × 105 g/mol) as Fluid Loss Control additive (FLA) for oil well cement was investigated. First, characteristic properties of CMHEC such as anionic charge amount, intrinsic viscosity in cement pore solution, and static filtration properties of cement slurries containing CMHEC were determined at 27°C and 70 bar. Effectiveness of the FLA was found to rely on reduction of cement filter cake permeability. Consequently, the working mechanism is ascribed to constriction of cement filter cake pores. Zeta potential measurements confirm that at low CMHEC dosages (0–0.3% by weight of cement, bwoc), adsorption of the polymer onto the surface of hydrating cement occurs. However, at dosages of 0.4% bwoc and higher, an associated polymer network is formed. This was evidenced by a strong increase in hydrodynamic diameter of solved CMHEC molecules, an exponential increase in viscosity and a noticeable reduction of surface tension. Thus, the working mechanism of CMHEC changes with dosage. At low dosages, adsorption presents the predominant mode of action, whereas above a threshold concentration of ∼ 10 g/L (the “overlapping concentration”), formation of associated polymer networks is responsible for effectiveness of CMHEC. Addition of anionic polyelectrolytes (e.g., sulfonated melamine formaldehyde polycondensate, Mw 2.0 × 105 g/mol) to cement slurries containing CMHEC greatly improves Fluid Loss Control. Apparently, the presence of such polyelectrolytes causes the formation of colloidal associates from CMHEC to occur at lower dosages. Through this mechanism, effectiveness of CMHEC as cement Fluid Loss additive is enhanced. © 2011 Wiley Periodicals, Inc. J Appl Polym Sci, 2012
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polyelectrolyte complexes from polyethylene imine acetone formaldehyde sulfite polycondensates a novel reagent for effective Fluid Loss Control of oil well cement slurries
Journal of Applied Polymer Science, 2011Co-Authors: Fatima Dugonjicbilic, Johann PlankAbstract:When used by itself, polyethylene imine (PEI) does not perform well as cement Fluid Loss additive. Its combination with acetone formaldehyde sulfite (AFS) polycondensate, however, exhibits excellent filtration Control. The mechanism underlying this synergistic effect was studied and the conditions producing best results were determined. For optimum performance, PEI and AFS must be reacted with each other to yield a polyelectrolyte complex (PEC) (d ∼ 5–10 μm), which effectively plugs the pores of the cement filter cake. Composition, size, and effectiveness of the PEC are strongly influenced by the anionic charge amount of the AFS dispersant. Ionic interactions between cationic imine functionalities of PEI and anionic sulfonate groups existing in AFS were confirmed by conductivity, infrared, zeta potential, and particle size measurements. For AFS samples possessing different degrees of sulfonation, the largest particle size and hence best Fluid Loss performance of the PEC was found to occur at a PEI:AFS molar ratio, which corresponds to neutral charge. Occurrence of large PEC particles (d ∼ 5 μm) within the cement filter cake pores was visualized by scanning electron microscopy, and their stability in highly alkaline cement pore solution was confirmed by particle size measurement. Other anionic polyelectrolytes may be used to yield such PECs with PEI to provide effective Fluid Loss Control for cement slurries. © 2011 Wiley Periodicals, Inc. J Appl Polym Sci, 2011
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competitive adsorption between an amps based Fluid Loss polymer and welan gum biopolymer in oil well cement
Journal of Applied Polymer Science, 2010Co-Authors: Johann Plank, Nils Recalde Lummer, Fatima DugonjicbilicAbstract:Water-soluble 2-acrylamido-2-methylpropane sulfonic acid (AMPS®)-based copolymers are commonly used to provide water retention (Fluid Loss Control) for oil well cement slurries. Here, the Fluid Loss performance of a CaAMPS®-N,N-dimethylacrylamide copolymer (CaAMPS®-co-NNDMA) in the presence of Welan gum, an anionic microbial biopolymer produced by anaerobic fermentation using Alcaligenes ATCC 31555 bacteria was investigated at 80°C. Welan gum is used to Control unwanted free water development at the surface of the cement slurry. The effectiveness of CaAMPS®-co-NNDMA Fluid Loss additive (FLA) solely relies on its high adsorption onto the positively charged surfaces of cement hydrates. Adsorption of the FLA is, however, perturbed by Welan gum. This anionic polysaccharide competes with CaAMPS®-co-NNDMA for adsorption sites on the cement surface. This effect is surprising because in cement pore solution, Welan gum exhibits a much lower specific anionic charge amount than CaAMPS®-co-NNDMA. The reason is that Welan gum possesses carboxylate functionalities, which are much stronger anchor groups than the sulfonate groups present in CaAMPS®-co-NNDMA. The superiority of the carboxylate groups regarding their affinity to the mineral surface, which possesses insufficiently coordinated Ca atoms is confirmed by a higher calcium binding capability for Welan gum than for the FLA. Thus, Welan gum can reduce effectiveness of CaAMPS®-co-NNDMA as Fluid Loss agent by preventing its adsorption or through displacement of already adsorbed FLA molecules from the surface of cement. In multiadmixture systems, which are commonly used in oil well cement, concrete or mortars, competitive adsorption between different additives for surface sites can negatively impact the performance of these additives. Understanding the reasons behind can help to develop more effective admixture systems. © 2010 Wiley Periodicals, Inc. J Appl Polym Sci, 2010
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modification of the molar anionic charge density of acetone formaldehyde sulfite dispersant to improve adsorption behavior and effectiveness in the presence of caamps co nndma cement Fluid Loss polymer
Journal of Applied Polymer Science, 2009Co-Authors: Johann Plank, Fatima Dugonjicbilic, Nils Recalde LummerAbstract:Sulfonated aldol polycondensates were synthesized from acetone, formaldehyde, and different amounts of sodium sulfite, resulting in polymers with varying degrees of sulfonation (DS). The anionic charge amount of these macromolecules measured by polyelectrolyte titration decreased with lower DS. The effectiveness of the acetone–formaldehyde–sulfite (AFS) polycondensates as cement dispersant was found to depend on the amount of polymer adsorbed on cement. AFS adsorption decreases with lower DS. Interaction and compatibility between AFS and CaAMPS®-co-NNDMA Fluid Loss additive was studied by formulating binary additive systems composed of one of the modified AFS polymers and CaAMPS-co-NNDMA. At high DS, AFS adsorbs strongly and prevents CaAMPS-co-NNDMA from adsorbing in sufficient amounts on the cement surface. The result is poor Fluid Loss Control of the cement slurry. AFS polymers with lower DS, however, allow simultaneous adsorption of both polymers in sufficient quantities to provide good Fluid Loss Control and low rheology at the same time. Thus, effectiveness of both additives was retained. Obviously, effectiveness of such multi-admixture systems depends on the adjustment of the adsorption behavior of the individual components relative to each other. Molar anionic charge density of the polymers was found to be a major parameter influencing their relative adsorption behavior. The AFS polymer with DS = 0.2 possesses a molar anionic charge density comparable to CaAMPS-co-NNDMA. Thus, when admixtures with similar molar anionic charge densities are used, the performance of one component is not negatively influenced by the other. © 2008 Wiley Periodicals, Inc. J Appl Polym Sci, 2009
Yili Kang - One of the best experts on this subject based on the ideXlab platform.
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lost circulation Control for formation damage prevention in naturally fractured reservoir mathematical model and experimental study
Spe Journal, 2017Co-Authors: Yili Kang, Lijun You, Zhenjiang YouAbstract:Drill-in Fluid Loss is the most important cause of formation damage during the drill-in process in fractured tight reservoirs. The addition of lost-circulation material (LCM) into drill-in Fluid is the most popular technique for Loss Control. However, traditional LCM selection is mainly performed by use of the trial-and-error method because of the lack of mathematical models. The present work aims at filling this gap by developing a new mathematical model to characterize the performance of drill-in Fluid-Loss Control by use of LCM during the drill-in process of fractured tight reservoirs. Plugging-zone strength and fracture-propagation pressure are the two main factors affecting drill-in Fluid-Loss Control. The developed mathematical model consists of two submodels: the plugging-zone-strength model and the fracture-propagation-pressure model. Explicit formulae are obtained for LCM selection dependent on the proposed model to Control drill-in Fluid Loss and prevent formation damage. Effects of LCMmechanical and geometrical properties on Loss-Control performance are analyzed for optimal fracture plugging and propagation Control. Laboratory tests on Loss-Control effect by use of different types and concentrations of LCMs are performed. Different combinations of acid-soluble rigid particles, fibers, and elastic particles are tested to generate a synergy effect for drill-in FluidLoss Control. The derived model is validated by laboratory data and successfully applied to the field case study in Sichuan Basin, China.
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analytical model of plugging zone strength for drill in Fluid Loss Control and formation damage prevention in fractured tight reservoir
Journal of Petroleum Science and Engineering, 2017Co-Authors: Chengyuan Xu, Yili Kang, Fei ChenAbstract:Developed fractures are beneficial for the efficient development of tight reservoir. They also lead to drill-in Fluid Loss and induce severe formation damage. Fracture plugging with Loss Control material (LCM) is the most common way to Control drill-in Fluid Loss in fractured formation. Fracture plugging effect largely depends on the strength of fracture plugging zone, because in most cases plugging failure is caused by the strength failure of plugging zone. However, the effects of LCM mechanical and geometric parameters on plugging zone strength are still unclear. Moreover, traditional LCM selection is mainly performed by trial-and-error method, due to the lack of mathematical models. This paper develops an analytical model for plugging zone strength accounting for the frictional failure and shear failure of fracture plugging zone. Effects of LCM mechanical and geometric properties on plugging zone strength are analyzed. The proposed model is validated by laboratory data. Application procedure of the proposed model to drill-in Fluid Loss Control is developed and successfully applied to the field case study in Sichuan basin, China. The modelling results show that particle-particle friction angle, particle-fiber friction angle, fiber tensile strength, D90 degradation rate, and friction angle between plugging zone and fracture surface are main mechanical parameters affecting the plugging zone strength. Particle size distribution, aspect ratio and initial angle of fiber, and plugging zone porosity are main geometric parameters during Loss Control. Single LCM parameters are applied to the selection of LCM type. Plugging zone parameters are used for the determination of optimal LCM concentration. Reasonable combination of rigid granule, fiber and elastic particle can create a synergy effect to optimize the plugging zone strength and Loss Control effect.
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review on formation damage mechanisms and processes in shale gas reservoir known and to be known
Journal of Natural Gas Science and Engineering, 2016Co-Authors: Chengyuan Xu, Yili Kang, Mingjun ChenAbstract:Producing natural gas from shale gas reservoir presents a great challenge to petroleum industry due to its low permeability nature. The process of gas release and production from shale reservoirs is Controlled by the combination of fractures and nano-pore network connected to micrometer pore network. However, the gas production after drill-in, completion and hydraulic fracturing are strongly influenced by formation damage and subsequent decrease of reservoir permeability and fracture conductivity. This paper reviews the main formation damage mechanisms during shale gas reservoir exploitation, including the physical and chemical damage. Formation damage types induced in drill-in, completion and stimulation processes are discussed in detail. Finally, the systematic evaluation method of formation damage, heat treatment and working Fluid Loss Control, as three further research directions for formation damage Control and removal are proposed for the efficient development of shale gas reservoirs.
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fracture plugging optimization for drill in Fluid Loss Control and formation damage prevention in fractured tight reservoir
Journal of Natural Gas Science and Engineering, 2016Co-Authors: Yili Kang, Fei Chen, Zhenjiang YouAbstract:Well-developed natural fractures are beneficial for the economic and efficient development of tight reservoirs. However, they also lead to drill-in Fluid Loss and induced severe formation damage. Fracture plugging with Loss Control material (LCM) is the most common way to Control lost circulation. Fracture plugging effect largely depends on the fracture propagation pressure, because plugging failure is mainly caused by fracture propagation in fractured formation. Nevertheless, the effects of the plugging parameters on the fracture propagation pressure are still unclear. The current paper develops a mathematical model for fracture propagation pressure accounting for fracture plugging. Key indexes are proposed for fracture plugging optimization based on parameter analysis. Laboratory experiments are conducted to select reasonable LCM type and concentration. The application procedure of the proposed model to drill-in Fluid Loss Control is presented and successfully applied to field case study. The modelling results show that the plugging zone length, width and permeability are the major plugging parameters that affect the fracture propagation pressure. The larger the plugging zone width and the smaller the plugging zone length and permeability, the higher the fracture propagation pressure. Maximum plugging pressure, total Loss volume before sealing and D90 degradation rate are proposed as the three indexes for LCM selection. Experimental results show that the combination of rigid granule, fiber and elastic particle can create a synergistic effect to optimize the fracture plugging effect. For the 500 μm width fracture, the optimal concentrations for rigid granule, fiber and elastic particle are 5.0%, 1.5% and 2.5%, respectively.
Reza Barati - One of the best experts on this subject based on the ideXlab platform.
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application of nanoparticles as Fluid Loss Control additives for hydraulic fracturing of tight and ultra tight hydrocarbon bearing formations
Journal of Natural Gas Science and Engineering, 2015Co-Authors: Reza BaratiAbstract:Abstract Fluid Loss into the matrix rock and micro-fractures is inevitable during a typical hydraulic fracturing job. This makes the application of a comparable Fluid Loss additive to reduce the filtrate volumes into microfractures of a shale formation necessary. Injection of polymeric solutions, either as slick water or cross-linked Fluids, in order to propagate a fracture and distribute proppants and keep the fracture open is a common practice in hydraulic fracturing of unconventional tight and ultra-tight formations. In addition to propagation of a main fracture, polymeric Fluids will be invading the already existing network of micro-fractures and extending the network connected to the main fracture. Different classes of nanoparticles have been used by several researchers to carry different agents including surfactants and enzymes for hydraulic fracturing purposes. Nano-sized pores and micro-sized fractures in tight and ultra-tight formations require a nano to micro-sized Fluid Loss additive to improve propagation of the hydraulic fractures by efficiently reducing the Fluid Loss. In this study, application of silica and polyelectrolyte complex (PEC) nanoparticles as Fluid Loss additives for three sets of core plugs with permeability values within the 10 −5 –10 −4 mD, 0.01–0.1 mD and 1–40 mD range was investigated. The nano-sized material used in this study significantly reduced the Fluid Loss volume for the cores with permeability values below 0.1 mD when mixed only with 2% KCl or with low concentrations of guar polymer prepared in 2% KCl.
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nanoparticles as Fluid Loss Control additives for hydraulic fracturing of tight and ultra tight hydrocarbon bearing formations
ASME 2014 33rd International Conference on Ocean Offshore and Arctic Engineering, 2014Co-Authors: Reza BaratiAbstract:Injection of polymeric solutions, either as slick water or cross-linked Fluids, in order to propagate a fracture and distribute proppants and keep the fracture open is a common practice in hydraulic fracturing of unconventional tight and ultra-tight formations. In addition to propagation of a main fracture, polymeric Fluids will be invading the already existing network of micro-fractures and extending the network connected to the main fracture. Fluid Loss into the matrix rock and micro-fractures is inevitable, so is the use of a comparable Fluid Loss additive to reduce the filtrate volume.Different classes of nanoparticles have been used by several researchers to carry different agents including surfactants and enzymes for hydraulic fracturing purposes. Nano-sized pores and micro-sized fractures in tight and ultra-tight formations require a nano to micro-sized Fluid Loss additive to improve propagation of the hydraulic fractures by efficiently reducing the Fluid Loss.In this study, application of silica and polyelectrolyte complex (PEC) nanoparticles as Fluid Loss additives for three sets of core plugs with permeability values within the 10−5 −10−4 mD, 0.01–0.1 mD and 1–40 mD range was investigated. The nano-sized material used in this study significantly reduced the Fluid Loss volume for the cores with permeability values below 0.1 mD when mixed only with 2% KCl or with low concentrations of guar polymer prepared in 2% KCl.Combination of the Fluid Loss additive application with chemical carrying application makes these nanoparticle systems a suitable package for hydraulic fracturing of tight and ultra-tight formations.Copyright © 2014 by ASME
James M Tour - One of the best experts on this subject based on the ideXlab platform.
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graphene oxide as a high performance Fluid Loss Control additive in water based drilling Fluids
ACS Applied Materials & Interfaces, 2012Co-Authors: Dmitry V Kosynkin, Gabriel Ceriotti, Kurt C Wilson, Jay R Lomeda, Jason T Scorsone, Arvind D Patel, James Friedheim, James M TourAbstract:Graphene oxide (GO) performs well as a filtration additive in water-based drilling Fluids at concentrations as low as 0.2 % (w/w) by carbon content. Standard American Petroleum Institute (API) filtration tests were conducted on pH-adjusted, aqueous dispersions of GO and xanthan gum. It was found that a combination of large-flake GO and powdered GO in a 3:1 ratio performed best in the API tests, allowing an average Fluid Loss of 6.1 mL over 30 min and leaving a filter cake ∼20 μm thick. In comparison, a standard suspension (∼12 g/L) of clays and polymers used in the oil industry gave an average Fluid Loss of 7.2 mL and a filter cake ∼280 μm thick. Scanning electron microscopy imaging revealed the extreme pliability of well-exfoliated GO, as the pressure due to filtration crumpled single GO sheets, forcing them to slide through pores with diameters much smaller than the flake’s flattened size. GO solutions also exhibited greater shear thinning and higher temperature stability compared to clay-based Fluid-lo...