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1
Tare, U. A., N. E. Takach, S. Z. Miska, F. B. Growcock, and N. Davis. "Investigation of Drilling Fluids Containing Blast Furnace Slag for Their Potential Impact on Formation Damage—A Laboratory Study." Journal of Energy Resources Technology 121, no. 3 (September 1, 1999): 149–53. http://dx.doi.org/10.1115/1.2795974.
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This work discusses the effect of incorporating blast furnace slag (BFS) as an additive in water-based drilling fluids. The intent of this treatment is rapid development of a thin, impervious, and easily removable filter cake, thereby minimizing detrimental impact of the drilling fluid on formation productivity as opposed to previous applications of BFS in universal fluids. To evaluate the impact of BFS on filter cake properties, permeability plugging apparatus (PPA) tests and dynamic formation damage (DFD) studies were conducted. Drill-in fluids and dispersed muds were tested using varying quantities of BFS. Once a steady rate of dynamic filter cake deposition was achieved, the BFS in the filter cakes was chemically activated. The results obtained from these activation studies were compared with those obtained with no BFS and with unactivated BFS. The nature of the filter cakes was examined with an environmental scanning electron microscope (ESEM). Results obtained from the PPA tests indicate substantial decreases in initial spurt loss and filtrate volume with increasing concentration of BFS. The DFD studies substantiate the aforementioned observations and show enhancement of return permeabilities with BFS activation. ESEM studies demonstrate that BFS can consolidate filter cakes.
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Moreira, Bruno Arantes, Flávia Cristina Assis Silva, Larissa dos Santos Sousa, Fábio de Oliveira Arouca, and João Jorge Ribeiro Damasceno. "Evaluation of Constitutive Equation for Stress in Solids in Porous Media Composed of Bridging Agents Used in Drilling Fluids." Materials Science Forum 727-728 (August 2012): 1878–83. http://dx.doi.org/10.4028/www.scientific.net/msf.727-728.1878.
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During oil well drilling processes in reservoir-rocks, the drilling fluid invades the formation, forming a layer of particles called filter cake. The formation of a thin filter cake and low permeability helps to control the drilling operation, ensuring the stability of the well and reducing the fluid loss of the liquid phase in the interior of the rocks. The empirical determination of the constitutive equation for the stress in solids is essential to evaluate the filtration and filter cake formation in drilling operations, enabling the operation simulation. In this context, this study aims to evaluate the relationship between the porosity and stress in solids of porous media composed of bridging agents used in drilling fluids. The concentration distribution in sediments was determined using a non-destructive technique based on the measure of attenuated gamma rays. The procedure employed in this study avoids the use of compression-permeability cell for the sediment characterization.
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Ma, Tianshou, Nian Peng, Ping Chen, and Yang Liu. "Transient response of near-wellbore supercharging during filter cake growth." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 76 (2021): 46. http://dx.doi.org/10.2516/ogst/2021028.
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Supercharging in the vicinity of a borehole is an important factor that affects formation damage and drilling safety, and the filter cake growth process has a significant impact on supercharging in the vicinity of the borehole. However, existing models that predict pore pressure distribution overlook dynamic filter cake growth. Thus, an analytical supercharging model was developed that considers time-dependent filter cake effects, and this model was verified using a two-dimensional numerical model. The influences of filter cake, formation, and filtrate properties on supercharging were investigated systematically. The results indicate that time-dependent filter cake effects have significant influence on supercharging. Supercharging increases in the early stage but decreases over time because of the dynamic growth of filter cake, and the supercharging magnitude decreases along the radial direction. Because of filter cake growth, the magnitude of supercharging falls quickly across the filter cake, and the decreased magnitude of pore pressure caused by the filter cake increases. Supercharging in low-permeability formations is more obvious and the faster rate of filter cake growth, a lower filtrate viscosity and faster reduction rate of filter cake permeability can help to weaken supercharging. The order of importance of influencing factors on supercharging is overbalance pressure > formation permeability > formation porosity ≈ filtrate viscosity > filter cake permeability attenuation coefficient > initial filter cake permeability control ratio > filter cake growth coefficient > filter cake porosity. To alleviate supercharging in the vicinity of the borehole, adopting drilling fluids that allow a filter cake to form quickly, optimizing drilling fluid with a lower filtrate viscosity, keeping a smaller overbalance pressure, and precise operation at the rig site are suggested for low-permeability formations during drilling.
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Feder, Judy. "Filter Cake Breaker Evaluation Scaled Up From Laboratory to Field Conditions." Journal of Petroleum Technology 73, no. 03 (March 1, 2021): 65–66. http://dx.doi.org/10.2118/0321-0065-jpt.
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This article, written by JPT Technology Editor Judy Feder, contains highlights of paper SPE 199260, “Filter Cake Breaker Evaluation for Water Injectors: Scale Up From Laboratory to Field Deployment,” by Pavithiran Chandran, SPE, Arunesh Kumar, SPE, and Iain Cameron, BP, et al., prepared for the 2020 SPE International Conference and Exhibition on Formation Damage Control, Lafayette, Louisiana, 19–21 February. The paper has not been peer reviewed. The complete paper describes the test procedures adopted for evaluating various filter cake breaker formulations and the work conducted to develop the systems to be ready for use in two North Sea fields (Field A and Field B). Water injection wells were planned to provide pressure support to oil producers in the two fields, and water-based drilling fluids were selected to drill the reservoir sections for both. The average permeability is 1000 md for Field A and 50–100 md for Field B. A laboratory study was commissioned to evaluate and optimize filter cake breaker systems for use in water injectors to efficiently remove external and internal filter cake to attain matrix injection without the need for backflow to clean the sandface. Introduction Field A was commissioned to drill 18 producers and seven water injectors from a semisubmersible drilling rig. Most of the injector wells are high-inclination, long openhole sections. Fluid density of 1.24–1.48 specific gravity (SG) (10.3–12.3 ppg) was required for wellbore stability. The Field B development plan included drilling 26 producers and 10 water injectors with an average injection rate target of 40,000 B/D of treated, produced water per well. Most wells are high-inclination to reduce the risk of direct fracture communication between wells. Injectivity indexes of 10–30 BWPD/psi were anticipated. The ability to include backflow/gas-lift capacity in the injector wells to assist cleanup was not included in the operational plan; therefore, direct injection was the preferred design standard. The injection interval in Field A features high-permeability (approximately 1000-md) zones; the Field B injection interval is considered a low-to-mid-permeability (approximately 100-md) zone. Injection of warm produced water into naturally occurring fractures in Field B injector wells yields poorer performance than when cooler fluids such as seawater are used. Higher downhole temperature and longer fluid residence time in the wellbore on Field B could increase the temperature of the injection fluid and thermally contract the natural fractures. Poor initial injectivity with produced water was identified as a potential risk on these wells, because this could lead to subsequent complications with seawater injection into these zones. Reservoir Drilling Fluid (RDF) Design and Selection Water-based RDF was chosen to drill the reservoir section of the water injectors on the basis of its ability to reduce operational complexity in terms of fluids preparation, displacement design, and screen running issues. RDF fluids typically contain a brine phase to achieve required density, xanthan polymer for viscosity, starch for filtration control, sized calcium carbonates for a bridging package, and specialized chemicals to address specific well challenges such as shale inhibitors and lubricants. Water-based RDF is more amenable than invert emulsion fluids to stimulation treatments for cleanup of filter cake and remediation of near-wellbore damage. However, water-based fluids can pose other operational issues such as increased torque and drag and potential for differential sticking, especially while drilling long horizontal wells, as was planned for both fields. A lubricant was included in the fluid used on Field B to manage torque-and-drag issues.
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Kok, M. V., and A. G. İşcan. "Estimation of Filter Cake Thickness for Water-based Drilling Fluids." Energy Sources, Part A: Recovery, Utilization, and Environmental Effects 32, no. 5 (January 4, 2010): 400–406. http://dx.doi.org/10.1080/15567030802464024.
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Shehata, Ali I., Mohamed Shokry, Khalid M. Saqr, and Mohamed Shehadeh. "Validation of a CFD Non-Newtonian Eulerian-Eulerian Model for Predicting Wellbore Filter Cake Formation." Applied Mechanics and Materials 819 (January 2016): 376–81. http://dx.doi.org/10.4028/www.scientific.net/amm.819.376.
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During oil wellbore drilling processes, filter cake is formed on the sidewalls of the well hole due to filtration of drilling fluid particles. The filter cake is crucial to the drilling process, since it helps to maintain the wellbore hole, protects the drilling bit from jamming and facilitates the subsequent phases of the well development. The most important parameter for filter cake formation is its thickness and its variation due to drilling conditions. In this paper, the drilling fluid particles filtration process was simulated at conditions mimicking deep wellbore drilling. The drilling fluid was simulated as a non-Newtonian two-phase fluid of liquid and particles, utilizing an Eulerian-Eulerian approach. The model successfully predicted a filter cake thickness which agrees well with measurements and previous CFD work.
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Siddig, Osama, Saad Al-Afnan, Salaheldin Elkatatny, and Mohamed Bahgat. "Novel Cake Washer for Removing Oil-Based Calcium Carbonate Filter Cake in Horizontal Wells." Sustainability 12, no. 8 (April 22, 2020): 3427. http://dx.doi.org/10.3390/su12083427.
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An impermeable layer “filter cake” usually forms during the overbalanced drilling technique. Even though it helps in protecting the formation from a further invasion of drilling fluids, the removal of this layer is essential for a proper cement job and to avoid any reduction in wellbore deliverability. The design of the removal process is complicated and depends on the filter cake composition and homogeneity. This paper presents an experimental evaluation on the usage of a novel cake washer (NCW) in the removal of a filter cake formed by an invert emulsion oil-based drilling fluid that contains calcium carbonate as a weighting material while drilling a horizontal reservoir. The proposed NCW is a mixture of organic acid, mutual solvent and nonionic surfactant. It is designed to enable restored wellbore permeability for a sustainable production. Since the filter cake mainly consists of the weighting material, the solubility of calcium carbonate in NCW at different ranges of temperature, duration and concentration was investigated. An actual casing joint was used to test the corrosion possibility of the treating solution. High-pressure and high-temperature (HPHT) filtration tests on ceramic discs and Berea sandstone core samples were conducted to measure the efficiency of the filter cake removal and the retained permeability. Ethylene glycol mono butyl ether (EGMBE) was used as a mutual solvent and the solubility was higher compared to when the mutual solvent was not used in the washer formulation. A significant increase in calcium carbonate dissolution with time was observed for a duration of 24 h. The solubility was found to be proportional to the concentration of NCW with optimum results of 99% removal at a temperature of around 212 °F. At those conditions, no major corrosion problems were detected. Permeability of the core retained its pristine value after the treatment.
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Veisi, Erfan, Mastaneh Hajipour, and Ebrahim Biniaz Delijani. "Experimental study on thermal, rheological and filtration control characteristics of drilling fluids: effect of nanoadditives." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 75 (2020): 36. http://dx.doi.org/10.2516/ogst/2020033.
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Cooling the drill bit is one of the major functions of drilling fluids, especially in high temperature deep drilling operations. Designing stable drilling fluids with proper thermal properties is a great challenge. Identifying appropriate additives for the drilling fluid can mitigate drill-bit erosion or deformation caused by induced thermal stress. The unique advantages of nanoparticles may enhance thermal characteristics of drilling fluids. The impacts of nanoparticles on the specific heat capacity, thermal conductivity, rheological, and filtration control characteristics of water‐based drilling fluids were experimentally investigated and compared in this study. Al2O3, CuO, and Cu nanoparticles were used to prepare the water-based drilling nanofluid samples with various concentrations, using the two-step method. Transmission Electron Microscopy (TEM) and X-Ray Diffraction (XRD) were utilized to study the nanoparticle samples. The nanofluids stability and particle size distribution were, furthermore, examined using Dynamic Light Scattering (DLS). The experimental results indicated that thermal and rheological characteristics are enhanced in the presence of nanoparticles. The best enhancement in drilling fluid heat capacity and thermal conductivity was obtained as 15.6% and 12%, respectively by adding 0.9 wt% Cu nanoparticles. Furthermore, significant improvement was observed in the rheological characteristics such as the apparent and plastic viscosities, yield point, and gel strength of the drilling nanofluids compared to the base drilling fluid. Addition of nanoparticles resulted in reduced fluid loss and formation damage. The permeability of filter cakes decreased with increasing the nanoparticles concentration, but no significant effect in filter cake thickness was observed. The results reveal that the application of nanoparticles may reduce drill-bit replacement costs by improving the thermal and drilling fluid rheological characteristics and decrease the formation damage due to mud filtrate invasion.
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Bageri, Badr S., Mohammed Benaafi, Mohamed Mahmoud, Shirish Patil, Abdelmjeed Mohamed, and Salaheldin Elkatatny. "Effect of Arenite, Calcareous, Argillaceous, and Ferruginous Sandstone Cuttings on Filter Cake and Drilling Fluid Properties in Horizontal Wells." Geofluids 2019 (April 16, 2019): 1–10. http://dx.doi.org/10.1155/2019/1956715.
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Fine, small-size, drilled cuttings, if not properly separated using mud conditioning equipment at the surface, are circulated with the drilling fluid from the surface to the bottom hole. These drilled cuttings have a significant effect on the drilling fluid properties and filter cake structure. During drilling long lateral sandstone formations, different cuttings with varied properties will be generated due to sandstone formations being heterogeneous and having different mineralogical compositions. Thus, the impact of these cuttings on the drilling fluid and filter cake properties will be different based on their mineralogy. In this paper, the effect of different sandstone formation cuttings, including arenite (quartz rich), calcareous (calcite rich), argillaceous (clay rich), and ferruginous (iron rich) sandstones, on the filter cake and drilling fluid properties was investigated. Cuttings of the mentioned sandstone formations were mixed with the drilling fluid to address the effect of these minerals on the filter cake thickness, porosity, and permeability. In addition, the effect of different sandstone formation cuttings on drilling fluid density and rheology, apparent viscosity (AV), plastic viscosity PV), and yield point (YP) was investigated. High-pressure high-temperature (HPHT) fluid loss test was conducted to form the filter cake. The core sample’s petrophysical properties were determined using X-ray fluorescence (XRF) and X-ray diffraction (XRD) techniques and scanning electron microscopy (SEM). The results of this work indicated that all cutting types increased the rheological properties when added to the drilling fluid at the same loadings but the argillaceous sandstone (clay rich) has a dominant effect compared to the other types because the higher clay content enhanced the rheology. From the filter cake point of view, the ferruginous sandstone improved the filter cake sealing properties and reduced its thickness, while the argillaceous cuttings degraded the filter cake porosity and permeability and allowed the finer cuttings to penetrate deeply in the filter medium.
10
Sedaghatzadeh, Mostafa, Khalil Shahbazi, Mohammad Hossein Ghazanfari, and Ghasem Zargar. "The Impact of Nanoparticles Geometry and Particle Size on Formation Damage Induced by Drilling Nano-Fluid during Dynamic Filtration." Journal of Nano Research 43 (September 2016): 81–97. http://dx.doi.org/10.4028/www.scientific.net/jnanor.43.81.
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In this paper, the impact of three parameters including nanoparticles geometry, particles aggregation and borehole inclination on induced formation damage from water based drilling fluids were investigated by means of experimental studies. Accordingly, we designed a dynamic filtration setup capable to rotate and change well inclination. nanobased drilling fluids consisting of spherical, cubical and tubular shapes nanoparticles as fluid loss additives were used. Mud cake quality, core permeability impairment and degree of formation damage at various well inclinations were examined. The cluster structure of aggregated particles were determined using fractal theory and applying dynamic light scattering technique. For this purpose, drilling fluids were circulated at different well inclinations and at a constant differential pressure against a synthetic core. Field emission scanning electronic microscopy images taken from mud cakes confirmed the proposed cluster structures of nanoparticles. The experimental results show that the mud cake quality and degree of damage are functions of produced structure of aggregated particles. Moreover, by increasing the well inclination, the skin factor increases. However, this trend is intensively depended on particle geometry. Real time analysis of pore throat size to particle size ratio during mud circulation shows the tendency of particles to create external/internal filter cake is mainly related to well inclination and particle shape. The results can be used to optimize the size and shape of selected macro/nanoparticles as additives in drilling fluids to reduce formation damage in directional and horizontal wells during drilling operation.
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Alvi, Muhammad Awais Ashfaq, Mesfin Belayneh, Sulalit Bandyopadhyay, and Mona Wetrhus Minde. "Effect of Iron Oxide Nanoparticles on the Properties of Water-Based Drilling Fluids." Energies 13, no. 24 (December 19, 2020): 6718. http://dx.doi.org/10.3390/en13246718.
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In recent years, several studies have indicated the impact of nanoparticles (NPs) on various properties (such as viscosity and fluid loss) of conventional drilling fluids. Our previous study with commercial iron oxide NPs indicated the potential of using NPs to improve the properties of a laboratory bentonite-based drilling fluid without barite. In the present work, iron oxide NPs have been synthesized using the co-precipitation method. The effect of these hydrophilic NPs has been evaluated in bentonite and KCl-based drilling fluids. Rheological properties at different temperatures, viscoelastic properties, lubricity, and filtrate loss were measured to study the effect of NPs on the base fluid. Also, elemental analysis of the filtrate and microscale analysis of the filter cake was performed. Results for bentonite-based fluid showed that 0.019 wt% (0.1 g) of NPs reduced the coefficient of friction by 47%, and 0.0095 wt% (0.05 g) of NPs reduced the fluid loss by 20%. Moreover, for KCl-based fluids, 0.019 wt% (0.1 g) of additive reduced the coefficient of friction by 45%, while higher concentration of 0.038 wt% (0.2 g) of NPs shows 14% reduction in the filtrate loss. Microscale analysis shows that presence of NPs in the cake structure produces a more compact and less porous structure. This study indicates that very small concentration of NPs can provide better performance for the drilling fluids. Additionally, results from this work indicate the ability of NPs to fine-tune the properties of drilling fluids.
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Adebayo, Abdulrauf R., and Badr S. Bageri. "A simple NMR methodology for evaluating filter cake properties and drilling fluid-induced formation damage." Journal of Petroleum Exploration and Production Technology 10, no. 4 (October 3, 2019): 1643–55. http://dx.doi.org/10.1007/s13202-019-00786-3.
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Abstract An efficient drilling fluid will form a filter cake that will minimize the drilling fluid invasion into any drilled formation. Drilling fluid must therefore be adequately evaluated in the laboratory prior to field trial. Filter cake properties such as thickness, porosity, permeability, and pore structure are frequently evaluated using several techniques such as CT scan, SEM, and XRF. However, each of these techniques can evaluate only one or two filter cake properties. This paper presents a simple but novel NMR technique to evaluate filter cake properties such as thickness, pore volume, porosity, and possibly permeability. Furthermore, the amount and particle size distribution of solids that invaded a given rock sample can be obtained using the same technique. The full procedure was tested and verified using four identical rock samples. Drilling fluid invasion and filter cake deposition experiments were conducted on each of the samples, using the same drilling fluid but four different concentrations of fluid loss additive. NMR T2 relaxation measurements were taken at three different stages of each rock sample: before filter cake deposition; after fluid invasion and filter cake deposition; and after filter cake removal. A material balance analysis of the probability density function and cumulative distribution function of the measured T2 profile at the different stages of each sample yielded multiple filtration loss properties of the filter cake. The results obtained showed high accuracy of the NMR versus the current techniques. Moreover, this current method evaluated the majority of the filter cake properties at the same time and in situ hence eliminated the need of using multi-procedures that disturb the sample state. Finally, the presented method can also be used to evaluate secondary damage associated with filter cake removal process.
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Junior, Agostinho C. B., Raphael R. Silva, Giovanna L. R. Leal, Tarsila M. Tertuliano, Rafael P. Alves, Alfredo I. C. Garnica, and Fabiola D. S. Curbelo. "The Influences of NP100 Surfactant and Pine-Oil Concentrations on Filtrate Volume and Filter-Cake Thickness of Microemulsion-Based Drilling Fluids (O/W)." Energies 14, no. 16 (August 13, 2021): 4965. http://dx.doi.org/10.3390/en14164965.
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In this work, nonionic surfactant NP100 and pine oil influences on the filtrate volume (FV) and the filter-cake thickness (thkns) of microemulsified drilling fluids were studied. A ternary phase diagram was obtained to define the microemulsion region, where a 2k factorial design was used with the addition of four center points and axial points. Twelve microemulsion points were defined and used later in the formulation of the investigated drilling fluids. The results showed that the increase in the surfactant and pine oil’s concentration increased FV and thkns, withthe oil phase being the most influential component in the filtrate volume and the surfactant being the most influential in the filter-cake thickness. Statistically significant models were obtained. The optimal concentrations were determined for the lowest FV and thkns; 45% of surfactant and 5% of pine oil for the filtrate volume (1.3 mL), and 45% of surfactant and 15% of pine oil for the filter-cake thickness (0.64 mm).
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Tariq, Zeeshan, Murtada Saleh Aljawad, Mohamed Mahmoud, Olalekan Alade, Muhammad Shahzad Kamal, and Ayman Al-Nakhli. "Reduction of Breakdown Pressure by Filter Cake Removal Using Thermochemical Fluids and Solvents: Experimental and Numerical Studies." Molecules 26, no. 15 (July 21, 2021): 4407. http://dx.doi.org/10.3390/molecules26154407.
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The process of well cleanup involves the removal of an impermeable layer of filter cake from the face of the formation. The inefficient removal of the filter cake imposes difficulty on fracturing operations. Filter cake’s impermeable features increase the required pressure to fracture the formation. In this study, a novel method is introduced to reduce the required breakdown pressure to fracture the formation containing the water-based drilling fluid filter cake. The breakdown pressure was tested for five samples of similar properties using different solutions. A simulated borehole was drilled in the core samples. An impermeable filter cake using barite-weighted drilling fluid was built on the face of the drilled hole of each sample. The breakdown pressure for the virgin sample without damage (filter cake) was 6.9 MPa. The breakdown pressure increased to 26.7 MPa after the formation of an impermeable filter cake. Partial removal of filter cake by chelating agent reduced the breakdown pressure to 17.9 MPa. Complete dissolution of the filter cake with chelating agents resulted in the breakdown pressure approximately equivalent to the virgin rock breakdown pressure, i.e., 6.8 MPa. The combined thermochemical and chelating agent solution removed the filter cake and reduced the breakdown pressure to 3.8 MPa. Post-treatment analysis was carried out using nuclear magnetic resonance (NMR) and scratch test. NMR showed the pore size redistributions with good communication between different pores after the thermochemical removal of filter cake. At the same time, there was no communication between the different pores due to permeability impairment after filter cake formation. The diffusion coupling through NMR scans confirmed the higher interconnectivity between different pores systems after the combined thermochemical and chelating agent treatment. Compressive strength was measured from the scratch test, confirming that filter cake formation caused added strength to the rock that impacts the rock breakdown pressure. The average compressive strength of the original specimen was 44.5 MPa that increased to 73.5 MPa after the formation of filter cake. When the filter cake was partially removed, the strength was reduced to 61.7 MPa. Complete removal with chelating agents removed the extra strength that was added due to the filter cake presence. Thermochemical and chelating agents resulted in a significantly lower compressive strength of 25.3 MPa. A numerical model was created to observe the reduction in breakdown pressure due to the thermochemical treatment of the filter cake. The result presented in this study showed the engineering applications of thermochemical treatment for filter cake removal.
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Dmytrenko, Viktoriia, and Yuliia Diachenko. "The impact assessment of plant oils on unctuousity of drilling fluids." Technology audit and production reserves 2, no. 3(58) (April 30, 2021): 25–30. http://dx.doi.org/10.15587/2706-5448.2021.229652.
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The object of study is natural oils. Lubricating additives based on natural substances – vegetable oils and animal fats – meet the increased requirements for environmental safety of materials used in the drilling process. Consumption of environmentally friendly lubricants is constantly growing and requires an expansion of the raw material base for their production. Therefore today lubricants are important drilling reagents. From the ecological point of view, lubricating additives based on vegetable oils are of the greatest interest. The main physicochemical properties of sunflower and castor vegetable oils and the influence of these lubricating additives on lubricating and rheological characteristics of drilling fluids were investigated. In addition, the main properties of water-clay drilling fluids were investigated and their main parameters were determined according to standard API methods. During the testing of the samples, we took into account, first of all, a shear rate of the filter cake (CFC). It is the value that characterizes the strength of filter cake and is determined by the ratio of strength necessary for the tangential displacement of cyclic load across the cake to its weight. It is the CFC that characterizes the lubricating properties of the samples of solutions with a lubricant additive of a certain concentration that were studied. It is the CFC that characterizes the lubricating properties of the samples of solutions with a lubricant additive of a certain concentration that were studied. Based on the above studies, it can be concluded that the addition of castor oil effectively reduces the coefficient of friction of the filtration crust formed from the studied drilling fluids (fresh, mineralized, and saline). The recommended concentrations of this oil to the drilling fluid are 0.5 %, 1 %, and 5 %. Sunflower oil has an effective effect on the saline solution, less effectively – on the mineralized with an oil concentration of 0.5 %, 3 %, and 5 %. On the basis of the conducted researches the prospects of use of sunflower and castor oils at development of a new compounding of a greasing additive to a drilling mud are defined. Further research is aimed at assessing their lubricity in the drilling fluid at the friction limit «metal-metal». It is planned to repeat the study at the Sticking Tester OFI (USA).
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Cerasi, P., and K. Soga. "Failure modes of drilling fluid filter cake." Géotechnique 51, no. 9 (November 2001): 777–85. http://dx.doi.org/10.1680/geot.2001.51.9.777.
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Ye, Qin Qin, Yong Zhang Zhou, and Dong Sheng Chen. "Cleaning Technology on Filter Cake of Silicate-Based Polymer Drilling Fluid." Applied Mechanics and Materials 310 (February 2013): 107–11. http://dx.doi.org/10.4028/www.scientific.net/amm.310.107.
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In order to evaluate the cleaning effect on filter cake, a set of test device was designed. The cleaning fluid formula and parameters which were elected by experiments were optimized. The weight of the filter cake before and after cleaning was analyzed by wet weight method. New alkaline flush fluid formula was confirmed finally and the washing technology suitable for filter cake of silicate-based polymer drilling fluid has been studied out. The effect of core permeability after cleaning has also been evaluated. The experimental results showed that No.5 formula was suitable for the cleaning filter cake of silicate-based drilling fluid filter, and the weight loss rate could reach 94.09% when cleaning time was 60 minutes. The rotating speed played a minor role in cleaning effect. Weight loss rates increased with the increase of temperature. The weight loss reached 100% when temperature was 90°C. The cleaning fluid could inprove the core permeability up to 900.13% after cleaning, which indicated that the cleaning fluid formula had efficient effect on cleaning filter cake of silicate-based polymer drilling fluid.
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Araújo, Elayne A., Thaine T. Caminha, Evanice M. Paiva, Raphael R. Silva, Júlio Cézar O. Freitas, Alfredo Ismael C. Garnica, and Fabíola D. S. Curbelo. "Application of Microemulsion Systems in the Formulation of Biodegradable Pre-Flush Fluid for Primary Cementing." Energies 13, no. 18 (September 9, 2020): 4683. http://dx.doi.org/10.3390/en13184683.
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Oil well cleanup fluids (pre-flushes) are intermediate fluids pumped ahead of the cement slurry; they are able to clean the well walls by removing the filter cake formed by the drilling fluid, and leave the surface water-wet. This work’s main objective was to use biodegradable microemulsion systems as cleanup fluids in order to reduce the environmental impact. Three microemulsion systems were formulated, each composed of an oil phase, a surfactant and three different aqueous phases: glycerol, glycerol:water (mass ratio 1:1), and fresh water. The results show that all microemulsion systems were effective with 100% filter cake removal, with a removal time of less than 60 s. The wettability test and fluid compatibility analyses exhibited advantageous performances, without phase separation, variations in viscosity, gelation, or flocculation. The compressive strength and X-ray diffractometry (XRD) analysis showed the influence of the glycerol on the cement slurry properties, with the compressive strength resistance ranging from 8.0 to 10.7 MPa, and resulted in the formation of portlandite.
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Nandurdikar, Neeraj S., Nicholas E. Takach, and Stefan Z. Miska. "Chemically Improved Filter Cakes for Drilling Wells." Journal of Energy Resources Technology 124, no. 4 (November 20, 2002): 223–30. http://dx.doi.org/10.1115/1.1492841.
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Blast furnace slag (BFS) is a latent hydraulic material similar in composition to Portland cement. BFS was originally studied for mud to cement (MTC) purposes. This application called for large quantities of BFS (40–500 ppb (lb/bbl)) and ultimately proved to be ineffective. Subsequently, BFS has been investigated as an additive in drilling fluids. In a recent study, muds containing additive-level concentrations (5–30 lb/bbl) of BFS were shown to be effective in reducing formation damage. The present work extends the investigation of BFS as a drilling fluid additive. Specifically, we have explored the use of chemical reagents to activate the BFS in filter cakes to achieve cakes that are thin, impervious and firm. Filter cakes were formed from slag-laden drilling fluids in a high-pressure, high-temperature reverse filtration apparatus (permeability plugging apparatus). Studies were conducted with partially hydrolyzed polyacrlyamide (PHPA) muds and CaCO3-based fluids containing different loadings of BFS. Filter cakes of these fluids were treated with several different activators and the results were compared to cakes containing no BFS. Different activation techniques were investigated and a novel device was designed to measure the strength of the filter cakes. An environmental scanning electron microscope examined the relationship between the structural features of the activated cakes and their strengths. This study demonstrates that filter cakes containing BFS can be chemically activated to produce thin, firm cakes with improved filtration properties. These cakes should be able to form better bonds with cement subsequently used for completion.
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Mei, Yu Kun, Ming Li, Lu Liu, Biao Zhou, and Xiao Yang Guo. "Research of Influences on Second Interface Cementation Performance in Well Cementation of Adding Metakaolin into Drilling Fluid." Materials Science Forum 847 (March 2016): 519–26. http://dx.doi.org/10.4028/www.scientific.net/msf.847.519.
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It is difficult for conventional drilling fluid filter cake to form integration cementation with cement sheath, which causing weak cementation of the second interface. Therefore the following researches on improving the second interface cementation strength were carried out based on alkali activation mechanism of metakaolin. Cementation strength between metakaolin drilling fluid filter cake and cement sheath has been observed; the mechanism has been analyzed through SEM, XRD and FT-IR; engineering application performance of metakaolin drilling fluid has been studied; and circulation time of the technology has been researched. The results of the experiments showed that: 1) adding metakaolin into drilling fluid was helpful to improve the second interface cementing performance; 2) calcium hydroxide produced by cement hydration inspired metakaolin to generate C-S-H gel and realized overall cementation of filter cake and cement sheath; 3) through select particle size of metakaolin matched with other solids in drilling fluid, drilling fluid performance index could meet requirements of engineering application; 4) and for best results, the circulation time of metakaolin drilling fluid should be more than 40 minutes. The results prove that metakaolin drilling fluid can improve the second interface cementation performance, showing feasibility on flied using and practical values on improving wellbore integrity.
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Li, Zhi Yong, Jie Nian Yan, Guang Cheng Jiang, Shui Xiang Xie, Ying Jun Fu, Wei Wei Zang, and Shuai Wei Yang. "The Research on Smart Drill-In Fluid Design." Advanced Materials Research 146-147 (October 2010): 1075–79. http://dx.doi.org/10.4028/www.scientific.net/amr.146-147.1075.
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There are continuous high concerns on formation protection technology in international petroleum engineering field. The reservoir drill-in fluid (RDF) is the first non-native fluid to contact formation, and which influences directly the ultimate capacity of oil and gas well. The paper discusses the smart RDF design method based on conventional drilling fluid. The designed RDF system is characterized as good formation damage control, as well as the performance easily adjusted for field application. The technology combines ideal packing technology with active calcium carbonate to obtain low permeability filter cake, high return permeability and low initial flowing pressure. The sized calcium carbonates contribute to develop sealing zone for preventing filtrate and solids from invading into formation, and the organophilic passageway in filter cake (the active calcium carbonate) is favorable to open automatically passageway for oil and gas during production. Different modifiers used to ground calciumcarbonate surface modification are evaluated in laboratory. And the laboratory results show modified calcium carbonates are comfortable with conventional drilling fluids additives such as XC(Xanthan ), potassium polyacrylate(K-PAM), sodium carboxymethyl cellulose(Na-CMC).
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Leusheva, Ekaterina L., and Nazim T. Alikhanov. "Research of Bare-Free Drilling Fluids." Недропользование 21, no. 3 (December 15, 2021): 123–30. http://dx.doi.org/10.15593/2712-8008/2021.3.4.
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Mining and geological conditions for the development of new fields are becoming more difficult every year. Accordingly, the requirements for ensuring the environmental and technological safety of the drilling process are becoming more and more important. To ensure such a process, it is necessary to use correctly selected drilling fluids with proper characteristics: rheological parameters sufficient for effective cleaning of the well bottom, density sufficient to create back pressure, fluid loss to ensure a high-quality filter cake. Modern environmental requirements dictate the abandonment of hydrocarbon-based solutions. But when using water-based solutions, there are no suitable solutions, especially with their high density, since the use of barite can lead to a decrease in reservoir productivity. In this regard, the analysis of the problem and the search for options for creating water-based drilling fluids, weighted without the addition of barite, having the properties of maintaining the stability of the wellbore, ensuring safe drilling and opening productive formations without damaging the reservoir characteristics, was carried out. Such a solution was found in changing the base of the drilling fluid - highly mineralized fluids or solutions based on saturated brines. Brines must be created on the basis of inorganic salts that have good solubility, for example, chlorides, bromides. Due to the content of salts, the fluids have an inhibitory effect, and depending on the volume of dissolution, the density of the drilling fluids can be controlled. The scientific works of foreign and domestic scientists analyzed in the article have been published over the past five years, which indicates the relevance of this development. The selected compositions are presented and theoretically investigated, which were also tested in the field conditions.
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Zhao, Zhengguo, Xiaolin Pu, Luo Xiao, Gui Wang, Junlin Su, and Mingmin He. "Synthesis and properties of high temperature resistant and salt tolerant filtrate reducer N,N-dimethylacrylamide 2-acrylamido-2-methyl-1-propyl dimethyl diallyl ammonium chloride N-vinylpyrrolidone quadripolymer." Journal of Polymer Engineering 35, no. 7 (September 1, 2015): 627–35. http://dx.doi.org/10.1515/polyeng-2014-0260.
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Abstract N,N-dimethylacrylamide (DMAA), 2-acrylamido-2-methyl-1-propyl (AMPS), dimethyl diallyl ammonium chloride (DMDAAC) and N-vinylpyrrolidone (NVP) monomers were copolymerized to synthesize a zwitterionic copolymer filtrate reducer. The results of Fourier transform infrared (FTIR) spectroscopy and nuclear magnetic resonance (NMR) indicated that the molecular structure and chemical compositions of the quadripolymer matched with the design, and the result of the differential scanning calorimetry (DSC)-thermogravimetric analysis (TGA) showed that the polymer had good thermal stability. The effects of the quadripolymer on the properties and salt tolerance of drilling fluids were investigated. The environmental scanning electron microscope (ESEM) was used to observe the microstructure of the DMAA/AMPS/DMDAAC/NVP quadripolymer-bentonite system and filter cake of the drilling fluid added the copolymer. Results showed that a one space grid structure was formed by the molecular film with a hydrophobic association effect and electrostatic interaction between the groups in the positive and negative charges of the quadripolymer. It adsorbed and coated clay particles, and kept the particles distributing multilevels which contributed to forming a compact filter cake to reduce fluid loss. The spatial structure of the quadripolymer in drilling fluid could be destroyed partly by high temperatures, sodium and calcium, but the polymer still had a good effect on reducing fluid filtration.
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Gamal, Hany, Salaheldin Elkatatny, Salem Basfar, and Abdulaziz Al-Majed. "Effect of pH on Rheological and Filtration Properties of Water-Based Drilling Fluid Based on Bentonite." Sustainability 11, no. 23 (November 27, 2019): 6714. http://dx.doi.org/10.3390/su11236714.
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The design of drilling fluids is very important for the drilling operation success. The rheological properties play a key role in the performance of the drilling fluid. Therefore, studying the mud rheological properties of the water-based drilling fluid based on bentonite is essential. The main objectives of this study are to address the effect of pH changes on the rheological and filtration properties of the water-based drilling fluid based on bentonite and to provide a recommended pH range for this drilling fluid for a safe and high-performance drilling operation. Different samples of the water-based drilling fluid based on bentonite with different pH values were prepared, and the rheological properties such as plastic viscosity, yield point, and gel strength were measured. After that, the filtration test was performed under 300 psi differential pressure and 200 °F. The pH for the water-based drilling fluid based on bentonite significantly affects the mud rheology. The shear stress and shear rate relation were varying with the change in the pH. Increasing the pH from 8 to 12 resulted in decreasing the plastic viscosity by 53% and the yield point by 82%, respectively. The ratio of yield point / plastic viscosity was 1.4 for pH of 8 while it decreased to 0.5 for a pH of 11 and 12. There was a significant decrease in the gel strength readings by increasing the pH. The filtrate volume and filter cake thickness increased by increasing pH. The filtration volume increased from 9.5 cm3 to 12.6 cm3 by increasing the pH from 9 to 12. The filter cake thickness was 2 mm at 9 pH, while it was increased to 3.6 mm for 12 pH. It is recommended from the results to keep the pH of water-based drilling fluid based on bentonite in the range of 9 to 10 as it provides the optimum mud rheological and filtration properties. The findings of this study illustrated that keeping the pH in the range of 9 to 10 will reduce the plastic viscosity that will help in increasing the rate of penetration and reducing the required pump pressure to circulate the mud to the surface which will help to sustain the drilling operation. In addition, reducing the filtrate volume will produce a thin filter cake which will help in avoiding the pipe sticking and protect the environment. In general, optimizing the pH of the water-based drilling fluid based on bentonite in the range of 9 to 10 will improve the drilling operation and minimize the total cost.
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Mohamed, Abdelmjeed, Salaheldin Elkatatny, and Abdulaziz Al-Majed. "Removal of Calcium Carbonate Water-Based Filter Cake Using a Green Biodegradable Acid." Sustainability 12, no. 3 (January 30, 2020): 994. http://dx.doi.org/10.3390/su12030994.
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The filter cake is a very thin layer of solid particles deposited from the drilling fluid onto the surface of the drilled formation. This is essential during the drilling process as it reduces fluid filtrate invasion, contributing for the well’s integrity. When the drilling processes are over, this formation must be removed efficiently to allow for the primary cement jobs to be conducted efficiently, and for hydrocarbons to be produced without any restrictions. The removal process of the filter cake is challenging and requires specific techniques, depending on several factors including the filter cake homogeneity, drilling fluid components, weight of materials used, and the continuous phase of the drilling fluid (i.e., water or oil). This study evaluates the use of green biodegradable removal acid (GBRA) to dissolve calcium carbonate water-based filter cake. The removal efficiency of this new acid was analyzed using filtration and removal tests, conducted on a ceramic filter disc and real core samples at 212 °F. Then, the new formulation was subjected to physical properties measurements and biodegradation and corrosion tests. Furthermore, the performance of the new acid formulation was compared with 10 wt.% hydrochloric acid (HCl) to ensure its efficiency. The obtained results showed that the new acid formulation was effective at removing the filter cake, with a removal efficiency greater than 90%. The retained permeability was 100% and 94% with the ceramic filter disc and the real limestone core sample, respectively, confirming the good removal performance of the new acid formulation. The corrosion rate of GBRA (50 wt.%) at 212 °F was 0.032 lb/ft2, which was within the acceptable range according to oil industry practices (i.e., less than 0.05 lb/ft2 if the temperature is less than 250 °F), while HCl (10 wt.%) yielded a high corrosion rate of 0.68 lb/ft2.
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Elkatatny, Salah, Mohamed A. Mahmoud, and Hisham A. Nasr-El-Din. "Characterization of Filter Cake Generated by Water-Based Drilling Fluids Using CT Scan." SPE Drilling & Completion 27, no. 02 (June 1, 2012): 282–93. http://dx.doi.org/10.2118/144098-pa.
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Tariq, Zeeshan, Muhammad Shahzad Kamal, Mohamed Mahmoud, Olalekan Alade, and Ayman Al-Nakhli. "Self-destructive barite filter cake in water-based and oil-based drilling fluids." Journal of Petroleum Science and Engineering 197 (February 2021): 107963. http://dx.doi.org/10.1016/j.petrol.2020.107963.
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Ponmani, Swaminathan, R. Nagarajan, and Jitendra S. Sangwai. "Effect of Nanofluids of CuO and ZnO in Polyethylene Glycol and Polyvinylpyrrolidone on the Thermal, Electrical, and Filtration-Loss Properties of Water-Based Drilling Fluids." SPE Journal 21, no. 02 (April 14, 2016): 405–15. http://dx.doi.org/10.2118/178919-pa.
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Summary The challenges in drilling problems such as formation damage, pipe sticking, lost circulation, poor hole cleaning, and fluid loss need better solutions. Nanotechnology, by means of nanofluids, provides potential solutions for the development of improved water-based mud (WBM). This work presents the use of nanofluids of CuO and ZnO prepared in various base fluids, such as xanthan gum, polyethylene glycol, and polyvinylpyrrolidone (PVP), which are commonly used in oilfield operations, for the development of nanofluid-enhanced drilling mud (NWBM). In this paper, formulations of various nanofluids with varying concentrations of nanoparticles, such as 0.1, 0.3, and 0.5 wt%, were investigated for their effect on the thermal, electrical, and fluid-loss properties of NWBM. In addition, these results also were compared with those obtained with microfluids of CuO and ZnO for the microfluid-enhanced drilling mud (MWBM) to understand the effect of particle size. It is observed that the use of nanofluids in WBM helps to improve their thermal properties, with an associated direct impact on their cooling efficiency at downhole and surface conditions compared with those using microfluid. Filtration-loss and filter-cake-thickness studies on WBM, MWBM, and NWBM were also carried out with an American Petroleum Institute (API) filter press. It is observed that the fluid loss decreases with addition of the nanofluids and microfluids in WBM, with nanofluids showing an improved efficacy over microfluids. The studies, in general, bear testimony to the efficacy of nanofluids in the development of next-generation improved water-based drilling fluids suitable for efficient drilling.
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Guo, H., J. Voncken, T. Opstal, R. Dams, and P. L. J. L. J. Zitha. "Investigation of the Mitigation of Lost Circulation in Oil-Based Drilling Fluids by Use of Gilsonite." SPE Journal 19, no. 06 (May 16, 2014): 1184–91. http://dx.doi.org/10.2118/157751-pa.
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Summary Fluid-loss control is an essential property of oil-based mud (OBM) that can affect the success of drilling operations. This paper presents an investigation of the mitigation of lost circulation in OBM by use of leakoff-control-additive gilsonite. A simple physical model was developed to describe the static-filtration process considering the formation and properties of the filter cake. Both high-pressure/high-temperature (HP/HT) American Petroleum Institute (API) press and core-flow-filtration experiments were performed to evaluate the leakoff behavior of OBM. Core-filtration experiments were carried with the aid of a computerized-tomography (CT) scanner to monitor the invasion of the filtrate into the sandstone core at time intervals. In the long time limit, the model predicts that the fluid loss follows the classical Carter equation; that is, the volume of leakoff increases as the square root of time for the static filtration through a filter paper and through the sandstone core. Dual-mode filtration diminishes the rate of fluid loss considering the effect of emulsion. The model also provides a relation between pressure drop and filtrate rate, which can be used to estimate the permeability of filter cake in the experiment. The leakoff behavior with additive observed in the experiment is well-explained by the microstructure of rapid-buildup filter cake, which is mainly responsible for the control of fluid loss. The role of different components of OBM, such as solid particles, emulsion droplets, and additives, is discussed in light of our observations.
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Rasyid, Aly. "Pemanfaatan Wellbore Strengthening Agent Selama Pengeboran di Onshore Sumatera Bagian Utara Indonesia." Jurnal Jaring SainTek 1, no. 2 (June 18, 2020): 47–51. http://dx.doi.org/10.31599/jaring-saintek.v1i2.172.
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At northern part of Sumatera Indonesian onshore many drilling issues were encounteredin the area, in particular the overlying shales above the pay zones in the high deviatedtrajectory wells. Since the last well drilling in this area was 70’ era, so that limited data isanother drilling engineering challenge, especially to provide an accurate drilling fluid. Tocombat the drilling issues, utilization of pre-treated wellbore strengthening agent wasapplied to reduce well bore issues and strengthen the well with an effective filter cake. In Northern Sumatera Indonesian onshore well in Indonesia was used as a case study. First a brief understanding and fundamentals of geo-mechanics is described in reference to wellconstruction as well as filter cake fundamental to protect the hole stability. Results,observations and conclusions were drawn upon using a case study comparing a well ononshore in Indonesia which had many drilling problems such as stuck pipe/differentialsticking and washouts/hole enlargement issues related to well bore stability, after using thewellbore stability agent, the problems that encountered significantly decrease.
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Rugang, Y., J. Guancheng, Y. Longyun, L. Wei, and D. Tianqing. "The effect of inorganic salt on the structure of filter cake of water based drilling fluid." "Proceedings" of "OilGasScientificResearchProjects" Institute, SOCAR, no. 1 (March 30, 2014): 30–38. http://dx.doi.org/10.5510/ogp20140100185.
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Ghazali, Nurul Aimi, T. A. T. Mohd, Nur Hashimah Alias, A. Azizi, and A. A. Harun. "The Effect of Lemongrass as Lost Circulation Material (LCM) to the Filtrate and Filter Cake Formation." Key Engineering Materials 594-595 (December 2013): 68–72. http://dx.doi.org/10.4028/www.scientific.net/kem.594-595.68.
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Lost circulation is one of the most troublesome encountered in drilling due to uncontrolled flow of mud into the formation that likely to be caused of unsuccessful filter cake. The lost circulation material (LCM) is the additives that added to the drilling fluid to control loss of mud to the formation. In this research, the lemongrass was used as LCM. The objectives of this experiment are to investigate the effect of lemongrass as LCM to the filtrate and filter cake thickness and to determine the effective size of lemongrass as LCM. The experiments were conducted to measure the filtrate and filter cake thickness with different size and different based of drilling fluid. Low Pressure Low Temperature (LPLT) filter press is for water based mud (WBM) and High Pressure High Temperature (HPHT) filter press is for oil based mud (OBM) were used to perform the filtration process under static condition and constant filtration time which is 30 minutes. Both WBM and OBM are prepared four samples with three difference sizes of LCM and native mud. The sizes of lemongrass are 150 microns, 250 microns and 500 microns. After each experiment, the filtrate volume and filter cake thickness were determined to represent. The result shows that lemongrass able to perform a good LCM in both WBM and OBM based on filtrate volume and filter cake thickness. For WBM, the mud with LCM is lower filtrate volume than native mud which is less than 6.0 ml and for OBM, the mud with LCM is lower filtrate volume than native mud which is less than 5.0 ml. Both WBM and OBM show the thickness of filter cake obtained was in the range of 2 to 25 mm. The result also shows that the effective size of LCM is 150 micron due to less filtrate volume and filter cake thickness compare to other size of LCM which is 250 microns and 500 microns. The findings revealed that then lemongrass with the size of 150 microns is the suitable material to be used as LCM to replace conventional LCM.
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Mohamed, Abdelmjeed, Salem Basfar, Salaheldin Elkatatny, and Abdulaziz Al-Majed. "Prevention of Barite Sag in Oil-Based Drilling Fluids Using a Mixture of Barite and Ilmenite as Weighting Material." Sustainability 11, no. 20 (October 12, 2019): 5617. http://dx.doi.org/10.3390/su11205617.
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Drilling high-pressure high-temperature (HPHT) wells requires a special fluid formulation that is capable of controlling the high pressure and is stable under the high downhole temperature. Barite-weighted fluids are common for such purpose because of the good properties of barite, its low cost, and its availability. However, solids settlement is a major problem encountered with this type of fluids, especially at elevated downhole temperatures. This phenomenon is known as barite sag, and it is encountered in vertical and directional wells under static or dynamic conditions leading to serious well control issues. This study aims to evaluate the use of barite-ilmenite mixture as a weighting agent to prevent solids sag in oil-based muds at elevated temperatures. Sag test was conducted under static conditions (vertical and inclined) at 350 °F and under dynamic conditions at 120 °F to determine the optimum ilmenite concentration. Afterward, a complete evaluation of the drilling fluid was performed by monitoring density, electrical stability, rheological and viscoelastic properties, and filtration performance to study the impact of adding ilmenite on drilling fluid performance. The results of this study showed that adding ilmenite reduces sag tendency, and only 40 wt.% ilmenite (from the total weighting material) was adequate to eliminate barite sag under both static and dynamic conditions with a sag factor of around 0.51. Adding ilmenite enhanced the rheological and viscoelastic properties and the suspension of solid particles in the drilling fluid, which confirmed sag test results. Adding ilmenite slightly increased the density of the drilling fluid, with a slight decrease in the electrical stability within the acceptable range of field applications. Moreover, a minor improvement in the filtration performance of the drilling fluid and filter cake sealing properties was observed with the combined weighting agent. The findings of this study provide a practical solution to the barite sag issue in oil-based fluids using a combination of barite and ilmenite powder as a weighting agent to drill HPHT oil and gas wells safely and efficiently with such type of fluids.
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Avci, Emine, and Bayram Ali Mert. "The Rheology and Performance of Geothermal Spring Water-Based Drilling Fluids." Geofluids 2019 (May 2, 2019): 1–8. http://dx.doi.org/10.1155/2019/3786293.
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In this study, the rheological properties and performances of mud prepared with geothermal spring water to be used by geothermal drilling operators were examined at ambient and elevated temperatures. In this context, mud samples were prepared in the compositions detailed in the API specification by using five different geothermal spring water types and a distilled water type. Afterwards, density, apparent viscosity, plastic viscosity, yield point, gel strength, fluid loss, pH, and filter cake thickness of these samples were measured. The drilling muds were analyzed by means of rheological tests in accordance with the standards of the American Petroleum Institute (API). The experimental results have revealed that the mud prepared with geothermal water have lower viscosity and yield point compared to those prepared with freshwater at elevated temperatures. The stability of the muds decreases, especially at temperatures higher than 250°F, and they start to become flocculated. It was concluded that geothermal water-based muds have higher API fluid loss and cake thickness than the freshwater-based one. Therefore, it could be interpreted that the muds prepared with geothermal spring water will exhibit lower flow performance and lower ability of hole cleaning and rate of penetration compared to the freshwater muds. Hence, it is recommended that this kind of water should not be used to prepare drilling mud.
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Bageri, Badr S., Hany Gamal, Salaheldin Elkatatny, and Shirish Patil. "Effect of Different Weighting Agents on Drilling Fluids and Filter Cake Properties in Sandstone Formations." ACS Omega 6, no. 24 (June 10, 2021): 16176–86. http://dx.doi.org/10.1021/acsomega.1c02129.
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Basfar, Salem, Abdelmjeed Mohamed, Salaheldin Elkatatny, and Abdulaziz Al-Majed. "A Combined Barite–Ilmenite Weighting Material to Prevent Barite Sag in Water-Based Drilling Fluid." Materials 12, no. 12 (June 17, 2019): 1945. http://dx.doi.org/10.3390/ma12121945.
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Barite sag is a serious problem encountered while drilling high-pressure/high-temperature (HPHT) wells. It occurs when barite particles separate from the base fluid leading to variations in drilling fluid density that may cause a serious well control issue. However, it occurs in vertical and inclined wells under both static and dynamic conditions. This study introduces a combined barite–ilmenite weighting material to prevent the barite sag problem in water-based drilling fluid. Different drilling fluid samples were prepared by adding different percentages of ilmenite (25, 50, and 75 wt.% from the total weight of the weighting agent) to the base drilling fluid (barite-weighted). Sag tendency of the drilling fluid samples was evaluated under static and dynamic conditions to determine the optimum concentration of ilmenite which was required to prevent the sag issue. A static sag test was conducted under both vertical and inclined conditions. The effect of adding ilmenite to the drilling fluid was evaluated by measuring fluid density and pH at room temperature, and rheological properties at 120 °F and 250 °F. Moreover, a filtration test was performed at 250 °F to study the impact of adding ilmenite on the drilling fluid filtration performance and sealing properties of the formed filter cake. The results of this study showed that adding ilmenite to barite-weighted drilling fluid increased fluid density and slightly reduced the pH within the acceptable pH range (9–11). Ilmenite maintained the rheology of the drilling fluid with a minimal drop in rheological properties due to the HPHT conditions, while a significant drop was observed for the base fluid (without ilmenite). Adding ilmenite to the base drilling fluid significantly reduced sag factor and 50 wt.% ilmenite was adequate to prevent solids sag in both dynamic and static conditions with sag factors of 0.33 and 0.51, respectively. Moreover, HPHT filtration results showed that adding ilmenite had no impact on filtration performance of the drilling fluid. The findings of this study show that the combined barite–ilmenite weighting material can be a good solution to prevent solids sag issues in water-based fluids; thus, drilling HPHT wells with such fluids would be safe and effective.
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Guliyev, V. V. "Enhancement lubricity properties of water-based mud with nanoparticles." Azerbaijan Oil Industry, no. 10 (October 15, 2020): 70–74. http://dx.doi.org/10.37474/0365-8554/2020-10-70-74.
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Currently, a great number of drilling fluids with different additives are used all over the world. Such additives are applied to control the properties of the drilling mud. The main purpose for controlling is to achieve more effective and safe drilling process. This research work aims to develop Water-Based Mud (WBM) with a Coefficient of Friction (CoF) as low as Oil-Based Mud (OBM) and better rheological properties. As it is known, produced CoF by WBM is higher than OBM, which means high friction between wellbore or casing and drill string. It was the reason for studying the effect of nanosilica on drilling fluid properties such as lubricity, rheological parameters and filtrate loss volume of drilling mud. The procedures were carried out following API RP 13B and API 13I standards. Five concentrations of nanosilica were selected to be tested. According to the results obtained, it was defined that adding nanosilica into the mud decreases CoF of basic WBM by 26 % and justifies nanosilica as a good lubricating agent for drilling fluid. The decreasing trend in coefficient of friction and plastic viscosity for nanosilica was obtained until the concentration of 0.1 %. This reduction is due to the shear thinning or pseudoplastic fluid behavior. After 0.1 %, an increase at PV value trend indicates that it does not follow shear thinning behavior and after reaching a certain amount of dissolved solids in the mud, it acts like normal drilling fluid. The yield point of the mud containing nanoparticles was higher than the basic one. Moreover, a growth in the concentration leads to an increase in yield point value. The improvement of this fluid system cleaning capacity via hydraulics modification and wellhole stability by filter cake endurance increase by adding nanosilica is shown as well. The average well construction data of “Neft Dashlary” field was used for the simulation studies conducted for the investigation of hydraulics parameters of reviewed fluids for all series of experiments. The test results were accepted reliable in case of at least 3 times repeatability.
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Agwu, Okorie E., Anietie N. Okon, and Francis D. Udoh. "A Comparative Study of Diesel Oil and Soybean Oil as Oil-Based Drilling Mud." Journal of Petroleum Engineering 2015 (February 11, 2015): 1–10. http://dx.doi.org/10.1155/2015/828451.
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Oil-based mud (OBM) was formulated with soybean oil extracted from soybean using the Soxhlet extraction method. The formulated soybean mud properties were compared with diesel oil mud properties. The compared properties were rheological properties, yield point and gel strength, and mud density and filtration loss properties, fluid loss and filter cake. The results obtained show that the soybean oil mud exhibited Bingham plastic rheological model with applicable (low) yield point and gel strength when compared with the diesel oil mud. The mud density measurement showed that soybean OBM was slightly higher than diesel OBM with mud density values of 8.10 lb/gal and 7.98 lb/gal, respectively, at barite content of 10 g. Additionally, the filtration loss test results showed that soybean mud fluid loss volumes, water and oil, were 13 mL and 10 mL, respectively, compared to diesel oil mud volume of 15 mL and 12 mL. Furthermore, the filtration loss test indicated that the soybean oil mud with filter cake thickness of 2 mm had a cake characteristic of thin and soft while the diesel oil mud resulted in filter cake thickness of 2.5 mm with cake characteristic of firm and rubbery. In comparison with previous published works in the literature, the soybean oil mud exhibits superior rheological and filtration property over other vegetable oil-based muds. Therefore, the formulated soybean oil mud exhibited good drilling mud properties that would compare favourably with those of diesel oil muds. Its filter cake characteristic of thin and soft is desirable and significant to avert stuck pipe during drilling operations, meaning that an oil-based drilling mud could be formulated from soybean oil.
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Yao, Rugang, Guancheng Jiang, Wei Li, Tianqing Deng, and Hongxia Zhang. "Effect of water-based drilling fluid components on filter cake structure." Powder Technology 262 (August 2014): 51–61. http://dx.doi.org/10.1016/j.powtec.2014.04.060.
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Lohne, Arild, Liqun Han, Claas van Zwaag, Hans van Velzen, Anne-Mette Mathisen, Allan Twynam, Wim Hendriks, Roman Bulgachev, and Dimitrios G. Hatzignatiou. "Formation-Damage and Well-Productivity Simulation." SPE Journal 15, no. 03 (May 20, 2010): 751–69. http://dx.doi.org/10.2118/122241-pa.
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Summary In this paper, we describe a simulation model for computing the damage imposed on the formation during overbalanced drilling. The main parts modeled are filter-cake buildup under both static and dynamic conditions; fluid loss to the formation; transport of solids and polymers inside the formation, including effects of porelining retention and pore-throat plugging; and salinity effects on fines stability and clay swelling. The developed model can handle multicomponent water-based-mud systems at both the core scale (linear model) and the field scale (2D radial model). Among the computed results are fluid loss vs. time, internal damage distribution, and productivity calculations for both the entire well and individual sections. The simulation model works, in part, independently of fluid-loss experiments (e.g., the model does not use fluid-leakoff coefficients but instead computes the filter-cake buildup and its flow resistance from properties ascribed to the individual components in the mud). Some of these properties can be measured directly, such as particle-size distribution of solids, effect of polymers on fluid viscosity, and formation permeability and porosity. Other properties, which must be determined by tuning the results of the numerical model against fluid-loss experiments, are still assumed to be rather case independent, and, once determined, they can be used in simulations at altered conditions as well as with different mud formulations. A detailed description of the filter-cake model is given in this paper. We present simulations of several static and dynamic fluid-loss experiments. The particle-transport model is used to simulate a dilute particle-injection experiment taken from the literature. Finally, we demonstrate the model's applicability at the field scale and present computational results from an actual well drilled in the North Sea. These results are analyzed, and it is concluded that the potential effects of the mechanistic modeling approach used are (a) increased understanding of damage mechanisms, (b) improved design of experiments used in the selection process, and (c) better predictions at the well scale. This allows for a more-efficient and more-realistic prescreening of drilling fluids than traditional core-plug testing.
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Ma, Tianshou, Nian Peng, and Ping Chen. "Filter cake formation process by involving the influence of solid particle size distribution in drilling fluids." Journal of Natural Gas Science and Engineering 79 (July 2020): 103350. http://dx.doi.org/10.1016/j.jngse.2020.103350.
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Arinkoola, A. O,, K. K. Salam, T. O. Salawudeen, G. O. Abidemi, J. O. Hamed, M. O. Jimoh, O. A. Olufayo, and Y. M. Aladeitan. "Improvement of Filtration Properties of Treated Nigerian Bentonitic Clay Using Locally Sourced Bio-Materials." LAUTECH Journal of Civil and Environmental Studies 5, no. 1 (September 27, 2020): 114–30. http://dx.doi.org/10.36108/laujoces/0202/50(0121).
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Exploitation of Nigerian bentonitic clay deposit will offer economic advantage in terms of utilization for drilling purpose and prevent money spent on importation. Clay used for this analysis was beneficiated using sodium Carbonate (Na2CO3) and the change in the elemental composition of the raw clay sample and treated clay with was estimated using X-ray fluorescence spectroscopy (XRF). The treated clay and locally sourced bio-materials were added to the formulation of drilling fluid using Reduced Central Composite Design (RCCD). The fluid loss and cake thickness of prepared drilling fluid were determined using filter loss test kit. The result of the investigation show that the maximum recorded fluid loss was 14.4 ml/30mins at 100 psi while cake thickness values improved with addition of the bio-materials to the drilling fluid formulation when compared with the standard values.
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Y. Alssafar, Saifalden, and Faleh H. M. Al-Mahdawi. "New Study of Mgo Nps in Drilling Fluid to Reduce Stick-Slip Vibration in Drilling System." Iraqi Journal of Chemical and Petroleum Engineering 20, no. 2 (June 30, 2019): 51–59. http://dx.doi.org/10.31699/ijcpe.2019.2.7.
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Stick-slip is kind of vibration which associated with drilling operation in around the bottom hole assembly (BHA) due to the small clearance between drill string & the open hole and due to the eccentric rotating of string. This research presents results of specific experimental study that was run by using two types of drilling mud (Fresh water Bentonite & Polymer), with/without Nanoparticle size materials of MgO in various ratios and computes the rheological properties of mud for each concentration [Yield point, plastic viscosity, Av, PH, filter loss (30 min), filter cake, Mud Cake Friction, Friction Factor]. These results then were used to find a clear effects of Nanoparticle drilling mud rheology on stick - slip strength by several perspectives through a special “Torque and Drag” software which simulate the torque amount expected on BHA during drilling a vertical well in different conditions using real drilling string design that usually used in Iraqi oil fields. Thus to mitigate or to prevent stick–slip and cure the sequence events that could happen to both of drilling string and the well, i.e. Bit/BHA wear, pipe sticking, borehole instability and low Rate of penetration. Our study concluded that there are good reduction in the torque from (2031lb-ft) to (1823lb-ft) using polymer mud and torque reduction from (4000lb-ft) to (3450lb-ft) using Fresh Water Bentonite, these results do not include any breaking in the satisfactory range of other mud rheology.
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Ba geri, B. S., Mohamed Mahmoud, Abdulazeez Abdulraheem, S. H. Al-Mutairi, S. M. Elkatatny, and R. A. Shawabkeh. "Single stage filter cake removal of barite weighted water based drilling fluid." Journal of Petroleum Science and Engineering 149 (January 2017): 476–84. http://dx.doi.org/10.1016/j.petrol.2016.10.059.
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Luo, Hui Hong, Ze Hua Wang, Yu Xue Sun, and Han Jiang. "Study of Drilling Fluid System of Resisting the High Temperature of 220 Degrees." Advanced Materials Research 753-755 (August 2013): 130–33. http://dx.doi.org/10.4028/www.scientific.net/amr.753-755.130.
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Focus on the high temperature rheological stability and the fluid loss control of resistance to high temperature drilling fluid system, further determine system formula and the formula of the high temperature drilling fluid system should be optimized. Eventually, a kind of organo-silica drilling fluid system of excellent performance which is resistant to high temperature of 220 degrees has been developed, and the system performances have been evaluated. The high temperature-resistant organo-silica drilling fluid system is of good shale inhibition, lubricity and borehole stability. The fluid loss is low and the filter cake is thin and tight, which can effectively prevent bit balling. The sand-carrying ability is good and the rheological property is easy to control. The performances of drilling fluid remain stable under high salinity and the system can resist the pollution of 6%NaCl and 0.5%CaC12. The materials used in this system are non-toxic, non-fluorescent and suitable for deep well drilling.
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Elkatatny, Salaheldin, Tural Jafarov, Abdulaziz Al-Majed, and Mohamed Mahmoud. "Formation Damage Avoidance by Reducing Invasion with Sodium Silicate-Modified Water-Based Drilling Fluid." Energies 12, no. 8 (April 19, 2019): 1485. http://dx.doi.org/10.3390/en12081485.
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Drilling multilateral and horizontal wells through tight gas reservoirs is a very difficult task. The drilling fluid should be designed to reduce both fluid and solid invasion into the tight formation to avoid formation damage by aqueous phase trapping. The objective of this paper is to assess the effect of sodium silicate on the drilling fluid properties such as rheological and filtration properties. Rheological properties (RPs) were measured at different temperatures while the filtration test was performed at 300 °F and 300 psi differential pressure. A retained permeability calculation was determined to confirm the prevention of solid invasion. The rheological properties results confirmed that the optimal concentration of sodium silicate (SS) was 0.075 wt.% and at the same time, the temperature has no effect on the SS optimum concentration. Using 0.075 wt.% of SS reduced the filtrate volume by 53% and decreased the filter cake thickness by 65%. After mechanical removal of the filter cake, the return permeability of the tight sandstone core was 100% confirming the prevention of solid invasion. The computer tomography (CT) scanner showed that the CT number before and after the filtration test was very close (almost the same) indicating zero solid invasion and prevention of the formation damage.
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Chai, Jin Peng, and Zheng Song Qiu. "A Comparative Study between p-Aminobenzensulfonate-Phenol-Formaldehyde Condensate and Sulfomethylated Phenolic Resin as Drilling Mud Fluid Loss Reducer." Advanced Materials Research 1081 (December 2014): 31–37. http://dx.doi.org/10.4028/www.scientific.net/amr.1081.31.
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The p-aminobenzensulfonate-phenol-formaldehyde (APF) condensate is synthesized and characterized by FTIR and TGA analyses. Its properties as drilling mud fluid loss reducer are studied with respect to fluid loss and particle size distribution. In addition, the effect of salt on properties of APF condensate was discussed. Test results show that the APF condensate not only possesses higher thermal stability than sulfomethylated phenolic resin (SMP), a commercial drilling mud additive, but also achieves good property of fluid loss control by reducing the permeability of filter cake; the fluid-loss controlling properties of APF condensate dropped with the increase of concentrations of NaCl.
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Rugang, Y., P. Chunyao, Z. Zhenhua, and J. Dongxu. "Study on the structure of filter cake layer of water based drilling fluid." SOCAR Proceedings, no. 1 (March 31, 2017): 24–34. http://dx.doi.org/10.5510/ogp20170100304.
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Siddig, Osama, Ahmed Abdulhamid Mahmoud, and Salaheldin Elkatatny. "A review of different approaches for water-based drilling fluid filter cake removal." Journal of Petroleum Science and Engineering 192 (September 2020): 107346. http://dx.doi.org/10.1016/j.petrol.2020.107346.
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Magzoub, Musaab I., Saeed Salehi, Ibnelwaleed A. Hussein, and Mustafa S. Nasser. "Investigation of Filter Cake Evolution in Carbonate Formation Using Polymer-Based Drilling Fluid." ACS Omega 6, no. 9 (February 24, 2021): 6231–39. http://dx.doi.org/10.1021/acsomega.0c05802.
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