Relevant bibliographies by topics / Drilling Fluids, Filter Cake

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  1. Journal articles
  2. Dissertations / Theses
  3. Book chapters
  4. Conference papers

Academic literature on the topic 'Drilling Fluids, Filter Cake'

Author: Grafiati
Published: 4 June 2021
Last updated: 11 February 2022

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Journal articles on the topic "Drilling Fluids, Filter Cake"

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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.
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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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Dissertations / Theses on the topic "Drilling Fluids, Filter Cake"

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Rostami, Ameneh. "Development of Self-destructing Filter Cake." Thesis, 2010. http://hdl.handle.net/1969.1/ETD-TAMU-2010-08-8366.

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The main goal of drilling a horizontal well is to enhance productivity or injectory by placing a long distance drain-hole within the pay-zone. Poor drilling fluid design results in difficulties such as poor hole cleaning, excessive torque or drag, wellbore instability, stuck drill string, loss of circulation, subsurface pressure control, poor cement jobs, and difficulties associated with running electric logs and formation damage can result. Neither of the conventional chemical cleaning methods can overcome problems for filter-cake removal in long horizontal and maximum reservoir contact wells because of limitations such as the complex geometry of wells, non-uniform chemical distribution, low contact between cleaning fluids/filter cake, and high chemical reaction rate, especially at high temperatures. This study describes a novel self-destructing drilling fluid system. Filter cakes are formed from a formula of drilling fluid that have a mixture of solid acid precursor and particulate solid acid-reactive materials. Then in the presence of water, the solid acid precursor (polylactic acid) hydrolyzes and dissolves, generating acids that then dissolve the solid acid-reactive materials (calcite). It effectively stimulates the horizontal section right after drilling and eliminates acidizing, resulting in significant cost savings, and improves filter-cake removal, thus enhancing the performance of the treated wells. A series of experiments have been run in the lab to determine the efficiency of this new system. Properties of this drilling fluid are measured. Experiments on solid acid particle size showed that the best size-distribution of solid acid precursor and solid reactive material to make a self-destructing filter cake is fine particles of calcium carbonate used as weighting material with 150 microns polylactic acid as solid acid precursor. By comparison of the results of the experiments at different temperatures, 230 degrees F has been chosen as the best temperature for running experiments. The self-destructing drilling fluid systems need enough time for the solid acid to be hydrolyzed and therefore remove the filter cake. After 20 hours of contact with the water as the only cleaning solution, about 80 percent of the filter cake was removed. Calcite is found to be the dominant compound in the sample of remained filter cake, which was proved by x-ray diffraction tests. Secondary electron microscopy (SEM) results show the morphology of the remained filter cake sample and confirm the crystalline area of calcite.
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Elkatatny, Salaheldin Mahmoud. "New Techniques to Characterize and Remove Water-Based Drilling Fluids Filter Cake." Thesis, 2013. http://hdl.handle.net/1969.1/149400.

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Filter cake characterization is very important in drilling and completion operations. Heterogeneity of the filter cake plays a key role in the design of chemical treatments needed to remove the filter cake. The objectives of this study are to characterize the filter cake under static and dynamic conditions, evaluate the using of polylactic acid and chelating agents to remove calcium carbonate-based filter cake, assess glycolic acid to remove Mn3O4-based filter cake, and evaluate ilmenite as a weighting material for water-based drilling fluid. In order to characterize the filter cake, computer tomography (CT) was used in combination with the scanning electronic microscopy (SEM) to analyze the filter cake. A modified HPHT filter cell was developed to perform the filtration tests. A see-through-cell was used to check the compatibility of different chemicals that were used to remove the filter cake. The results obtained from the CT scan showed that the filter cake was heterogeneous and contained two layers with different properties under static and dynamic conditions. Under static conditions, the formation of filter cake changed from compression to buildup; while under dynamic conditions, the filter cake was formed under continuous buildup. Polylactic acid was used as a component of the drilling fluid components and the results obtained showed that the drill-in fluid had stable rheological properties up to 250˚F over 24 hrs. The removal efficiency of the filter cake was nearly 100% and the return permeability was about 100% for Indiana limestone and Berea sandstone cores, when using a weight ratio of polylactic acid to calcium carbonate 3 to 1. GLDA (pH 3.3) and HEDTA (pH 4) can be used to remove the filter cake in one step without using α-amylase enzyme solutions. GLDA (20 wt% in a 200 g solution and pH of 3.3) and HEDTA (20 wt% in a 200 g solution and pH 4) had 100% removal efficiency of the filter cake using Indiana limestone and Berea sandstone cores. Chelate solutions, GLDA (pH of 3.3 - 13) and HEDTA (pH of 4 and 7) were incompatible with α-amylase enzyme solutions over a wide range of temperatures. CT results showed that no formation damage was observed when using chelating agents as a breaker to remove the calcium carbonate filter cake. Manganese tetraoxide-based filter cake had a removal efficiency of 85% after 20 hrs soaking with glycolic acid (5 wt%) after soaking with α-amylase for 24 hrs, and 89% after reaction with acid mixture (1 wt% HCl and 7 wt% glycolic acid) for 16 hrs. for both methods, the retained permeability was 100% for Indiana limestone cores and 120% for Berea sandstone cores, which indication maximum productivity of these formations. Ilmenite-based filter cake was ideal for HPHT applications, 0.2 in. thickness and 12 cm3 filtrate under dynamic conditions. The filtrate volume was reduced by adding a minor amount of CaCO3 solids that improved the particles packing. No sag problem was observed when using the micronized ilmenite in water-based drilling fluids. Ilmenite has a negative zeta potential in alkaline media and had a stable dispersion in water at pH > 7.
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Al, Mojil Abdullah Mohammed A. "Removal of Filter Cake Generated by Manganese Tetraoxide Water-based Drilling Fluids." Thesis, 2010. http://hdl.handle.net/1969.1/ETD-TAMU-2010-08-8335.

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Three effective solutions to dissolve the filter cake created by water-based drilling fluids weighted with Mn3O4 particles were developed. Hydrochloric acid at concentration lower than 5 wt% can dissolve most of Mn3O4-based filter cake. Dissolving the filter cake in two-stage treatment of enzyme and organic acid was effective and eliminated the associated drawbacks of using HCl. Finally, combining low and safe concentration of HCl with an organic acid in one-stage treatment was very effective. Hydrochloric acid (10-wt%) dissolved 78 wt% of Mn3O4-based filter cake at 250°F after 28 hours soaking time. However, Chlorine gas was detected during the reaction of 5 to 15-wt% HCl with Mn3O4 particles. At 190°F, 1- and 4-wt% HCl dissolved most Mn3O4 particles (up to 70-wt% solubility). Their reactions with Mn3O4 particles followed Eq. 8 at 190°F, which further confirmed the absence of chlorine gas production at HCl concentrations lower than 5-wt%. EDTA and DTPA at high pH (12) and acetic, propionic, butyric, and gluconic acids at low pH (3-5) showed very low solubilities of Mn3O4 particles. GLDA, citric, oxalic, and tartaric acids produced large amount of white precipitation upon the reactions with Mn3O4 particles. Similarly, DTPA will produce damaging material if used to dissolve Mn3O4-based filter cake in sandstone formation. At 4-wt% acid concentration, lactic, glycolic, and formic acids dissolved Mn3O4 particles up to 76 wt% solubility at 190°F. Malonic acid at lower concentration (2-wt%) dissolved 54 wt% of Mn3O4 particles at 190°F. Manganese tetraoxide particles were covered with polymeric material (starch), which significantly reduced the solubility of filter cake in organic acids. Therefore, there was a need to remove Mn3O4-based filter cake in two-stage treatment. Enzyme-A (10-wt%) and Precursor of lactic acid (12.5-wt%) dissolved 84 wt% of the filter cake. An innovative approach led to complete solubility of Mn3O4 particles when low and safe concentration of HCl (1-wt%) combined with 4-wt% lactic acid at 190°F. HCl (1-wt%) combined with lactic acid (4-wt%), dissolved 85 wt% of the Mn3O4-based filter cake after 18-22 hours soaking time at 250°F in one stage treatment.
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Alotaibi, Mohammed Badri. "Characteristics and removal of filter cake formed by formate-based drilling mud." 2008. http://hdl.handle.net/1969.1/ETD-TAMU-2800.

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Formate-based mud has been used to drill deep gas wells in Saudi Arabia since 2004. This mud typically contains XC-polymer, starch, polyanionic cellulose, and a relatively small amount of calcium carbonate particles, and is used to drill a deep sandstone reservoir (310°F). Calcium carbonate particles are frequently used as weighting material to maintain the pressure that is required for well control and minimize the leak-off. Such solids become consolidated and trapped in the polymeric material and this makes the filter cake a strong permeability barrier. Various cleaning fluids were proposed to remove drilling mud filter cake; including: solid-free formate brine and formate brine doped with organic acids (acetic, formic, and citric acids), esters, and enzymes. The main objective of this research is to assess the effectiveness of these cleaning fluids in removing drilling mud filter cake. A dynamic high-pressure/high-temperature (HPHT) cell was used to determine characteristics of the drilling mud filter cake. Drilling mud and completion fluids were obtained from the field. Compatibility tests between potassium formate brine, cleaning fluids, and formation brine were performed at 300ºF and 200 psi using HPHT visual cells. Surface tensions of various cleaning fluids were also measured at high temperatures. The conventional method for cleaning the filter cake is by circulating solid-free formate brines at a high flow rate. This mechanical technique removes only the external drilling fluid damage. Citric acid at 10 wt%, formic acid, and lactic acid were found to be incompatible with formate brine at room temperature. However, these acids were compatible with formate brine at temperatures greater than 122°F. Only acetic acid was compatible with formate brine. A formula was developed that is compatible at room and reservoir temperature. This formula was effective in removing filter cake. A corrosion inhibitor was added to protect downhole tubulars. In general detail, this research will discuss the development of this formula and all tests that led to its development.
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Suri, Ajay. "Cleanup of internal filter cake during flowback." Thesis, 2005. http://hdl.handle.net/2152/2337.

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Dharwadkar, Pavan S. "Analyzing the Limits and Extent of Alpha-Amylase Catalyzed Removal of Starch-Based Filter Cake." Thesis, 2011. http://hdl.handle.net/1969.1/ETD-TAMU-2011-12-10422.

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The ability of starch to impart functions including fluid-loss control, cuttings transport, and rheological characteristics to water-based drilling fluids has led to its widespread use in the oil industry. The filter cake deposited by these drilling fluids often employs sized solid particles and starch to inhibit fluid loss into the formation. This inherently causes damage to the formation by impairing the permeability and must be removed before production. An alpha-amylase enzyme treatment was found to provide an effective approach to degrading starch in filter cake. In this work, an alpha-amylase enzyme treatment was analyzed by determining the extent of degradation of starch in filter cake using the iodine test, identifying degradants using high performance liquid chromatography, spectrophotometrically monitoring the concentration of enzyme, and measuring the cleanup efficiency of the enzyme treatment using a static filter press apparatus. The alpha-amylase enzyme used in this study was found to have a molecular weight under 30,000. The activity of the alpha-amylase enzyme was found to be sensitive to pH and temperature. The alpha-amylase enzyme was found to denature at temperatures above 165 degrees F and reversibly deactivate at pH below 4. Optimal conditions for alpha-amylase activity were found to be 150 degrees F and pH 6.5. The enzyme treatment works by hydrolyzing the interior glycosidic bonds of amylose and amylopectin residues of starch, creating soluble poly- and oligosaccharides and glucose. The enzyme treatment did not dissolve the calcium carbonate sized solids and a 5 wt. % hydrochloric acid postflush was necessary. The cleanup efficiency of the enzyme at pH 6.5 and room temperature treatment in conjunction with the postflush in a static test was 73% at 10% v/v concentration. Degradants resulting from alpha-amylase were identified chromatographically. Enzyme concentration remained steady prior to and after treatment.
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Book chapters on the topic "Drilling Fluids, Filter Cake"

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"Filter cake removal." In Petroleum Engineer's Guide to Oil Field Chemicals and Fluids, 299–316. Elsevier, 2015. http://dx.doi.org/10.1016/b978-0-12-803734-8.00009-6.

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Fink, Johannes Karl. "Filter Cake Removal." In Petroleum Engineer's Guide to Oil Field Chemicals and Fluids, 295–309. Elsevier, 2012. http://dx.doi.org/10.1016/b978-0-12-383844-5.00009-x.

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Fink, Johannes. "Filter cake removal." In Petroleum Engineer's Guide to Oil Field Chemicals and Fluids, 419–39. Elsevier, 2021. http://dx.doi.org/10.1016/b978-0-323-85438-2.00009-8.

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Gaurina-Medjimurec, Nediljka, and Borivoje Pasic. "Risk Due to Pipe Sticking." In Risk Analysis for Prevention of Hazardous Situations in Petroleum and Natural Gas Engineering, 47–72. IGI Global, 2014. http://dx.doi.org/10.4018/978-1-4666-4777-0.ch003.

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A stuck pipe is a common worldwide drilling problem in terms of time and financial cost. It causes significant increases in non-productive time and losses of millions of dollars each year in the petroleum industry. There are many factors affecting stuck pipe occurrence such as improper mud design, poor hole cleaning, differential pressure, key seating, balling up of bit, accumulation of cuttings, poor bottom hole assembly configuration, etc. The causes of a stuck pipe can be divided into two categories: (a) differential sticking and (b) mechanical sticking. Differential-pressure pipe sticking occurs when a portion of the drill string becomes embedded in a filter cake that forms on the wall of a permeable formation during drilling. Mechanical sticking is connected with key seating, formation-related wellbore instability, wellbore geometry (deviation and ledges), inadequate hole cleaning, junk in hole, collapsed casing, and cement related problems. Stuck pipe risk could be minimized by using available methodologies for stuck pipe prediction and avoiding based on available drilling parameters.
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Conference papers on the topic "Drilling Fluids, Filter Cake"

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Al Moajil, Abdullah Mohammad, Hisham A. Nasr-El-Din, Abdullah Saleh Al-Yami, Ali D. Al-Aamri, and Arwa Khalid Al-Agil. "Removal of Filter Cake Formed by Manganese Tetraoxide-Based Drilling Fluids." In SPE International Symposium and Exhibition on Formation Damage Control. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/112450-ms.

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2

Yidan, Li, Rosenberg Elisabeth, J. F. Argillier, Durrieu Josianne, and Montes Jose. "Correlation Between Filter Cake Structure and Filtration Properties of Model Drilling Fluids." In SPE International Symposium on Oilfield Chemistry. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/28961-ms.

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Elkatatny, S. M., M. A. Mahmoud, and H. A. Nasr-El-Din. "A New Approach to Determine Filter Cake Properties of Water-Based Drilling Fluids." In SPE/DGS Saudi Arabia Section Technical Symposium and Exhibition. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/149041-ms.

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4

Elkatatny, Salaheldin, Mohamed Ahmednasreldin Mahmoud, and Hisham A. Nasr-El-Din. "A New Technique to Characterize Drilling Fluid Filter Cake." In SPE European Formation Damage Conference. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/144098-ms.

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Al Moajil, Abdullah Mohammad, and Hisham A. Nasr-El-Din. "Reaction of Hydrochloric Acid With Filter Cake Created by Mn3O4 Water-Based Drilling Fluids." In Trinidad and Tobago Energy Resources Conference. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/133467-ms.

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6

Wagle, Vikrant, Abdullah Yami, Michael Onoriode, Jacques Butcher, and Nivika Gupta. "Low ECD High Performance Invert Emulsion Drilling Fluids: Lab Development and Field Deployment." In SPE/IADC Middle East Drilling Technology Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/202115-ms.

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Abstract The present paper describes the results of the formulation of an acid-soluble low ECD organoclay-free invert emulsion drilling fluid formulated with acid soluble manganese tetroxide and a specially designed bridging package. The paper also presents a short summary of field applications to date. The novel, non-damaging fluid has superior rheology resulting in lower ECD, excellent suspension properties for effective hole cleaning and barite-sag resistance while also reducing the risk of stuck pipe in high over balance applications. 95pcf high performance invert emulsion fluid (HPIEF) was formulated using an engineered bridging package comprising of acid-soluble bridging agents and an acid-soluble weighting agent viz. manganese tetroxide. The paper describes the filtration and rheological properties of the HPIEF after hot rolling at 300oF. Different tests such as contamination testing, sag-factor analysis, high temperature-high pressure rheology measurements and filter-cake breaking studies at 300oF were performed on the HPIEF. The 95pcf fluid was also subjected to particle plugging experiments to determine the invasion characteristics and the non-damaging nature of the fluids. The 95pcf HPIEF exhibited optimal filtration properties at high overbalance conditions. The low PV values and rheological profile support low ECDs while drilling. The static aging tests performed on the 95pcf HPIEF resulted in a sag factor of less than 0.53, qualifying the inherent stability for expected downhole conditions. The HPIEF demonstrated resilience to contamination testing with negligible change in properties. Filter-cake breaking experiments performed using a specially designed breaker fluid system gave high filter-cake breaking efficiency. Return permeability studies were performed with the HPIEF against synthetic core material, results of which confirmed the non-damaging design of the fluid. The paper thus demonstrates the superior performance of the HPIEF in achieving the desired lab and field performance.
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Bulgachev, R., W. Duran, G. Harpley, G. Hurst, R. Lee, A. Twynam, T. Thay, and A. Sookoo. "Novel Filter Cake Breaker Design and Successful Use for OHGP Carrier Fluid." In SPE/IADC Drilling Conference and Exhibition. Society of Petroleum Engineers, 2015. http://dx.doi.org/10.2118/173132-ms.

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Ravi, K. M., R. M. Beirute, and R. L. Covington. "Erodability of Partially Dehydrated Gelled Drilling Fluid and Filter Cake." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1992. http://dx.doi.org/10.2118/24571-ms.

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Kanjirakat, Anoop, Arnel Carvero, Reza Sadr, and Mahmood Amani. "INFLUENCE OF CNT-NANOPARTICLES IN THE FILTRATE CHARACTERISTICS AND FILTER CAKE FORMATION OF A WATER-BASED DRILLING FLUID." In 5th Thermal and Fluids Engineering Conference (TFEC). Connecticut: Begellhouse, 2020. http://dx.doi.org/10.1615/tfec2020.env.032112.

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Carlson, E. S., M. Venkataraman, P. E. Clark, T. R. Sifferman, M. D. Coffey, and J. M. Seheult. "Predicting the Fluid Loss of Drilling, Workover, and Fracturing Fluids into a Formation With and Without Filter Cake." In Permian Basin Oil and Gas Recovery Conference. Society of Petroleum Engineers, 1996. http://dx.doi.org/10.2118/35227-ms.

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