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Journal articles on the topic 'Maximum Drilling Fluid Temperature'

Author: Grafiati

Published: 4 June 2021

Last updated: 19 February 2022

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1

You, Fangyi, Jin Li, Huzi Cui, and Qiulian Dai. "Study of the influence of models on the drilling temperature of bone measured by thermocouples." Advanced Composites Letters 29 (January 1, 2020): 2633366X2092140. http://dx.doi.org/10.1177/2633366x20921406.

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Bone drilling is a standard procedure in medicine mainly for internal fixation with a gripper plate. Drilling bone generates much heat, then the heat causes the temperature of bone to rise, nearby the borehole rapidly, while drilling. Studies indicated that the bone would irreversibly be damaged after being heated up to 47°C for 60 s. Hence, it is vitally important to control the drilling temperature of bone. Two different models of the tibia for drilling simulation were established with ABAQUS software based on finite element analysis in this article. The first model is an approximate ideal m

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2

Zhou, Feng-shan, Zheng-qiang Xiong, Bao-lin Cui, et al. "Effect of Nitric Acid on the Low Fluorescing Performance of Drilling Fluid Lubricant Based Animal and Vegetable Oils." Journal of Spectroscopy 2013 (2013): 1–7. http://dx.doi.org/10.1155/2013/269280.

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After synthesis of mixed fatty acid triethanolamine ester surfactant based on animal and vegetable mixed oils, the reaction solution was added into 4% (wt/wt) liquid nitric acid or 9% (wt/wt) solid nitric acid as eliminating fluorescent agent continuing to react from 1 to 2 hours. The low fluorescence lubricant named E167 for drilling fluid was prepared, in which maximum fluorescence intensity (Fmax) was less than 10 in three-dimensional fluorescence spectra of excitation wavelength range. When the E167 was added into fresh water based drilling fluid at the dosage of 0.5% (wt/wt), the sticking

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3

Jia, Hu, Yao–Xi Hu, Shan–Jie Zhao, and Jin–Zhou Zhao. "The Feasibility for Potassium-Based Phosphate Brines To Serve as High-Density Solid-Free Well-Completion Fluids in High-Temperature/High-Pressure Formations." SPE Journal 24, no. 05 (2018): 2033–46. http://dx.doi.org/10.2118/194008-pa.

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Summary Many oil and gas resources in deep–sea environments worldwide are often located in high–temperature/high–pressure (HT/HP) and low–permeability reservoirs. The reservoir–pressure coefficient usually exceeds 1.6, with formation temperature greater than 180°C. Challenges are faced for well drilling and completion in these HT/HP reservoirs. A solid–free well–completion fluid with safety density greater than 1.8 g/cm3 and excellent thermal endurance is strongly needed in the industry. Because of high cost and/or corrosion and toxicity problems, the application of available solid–free well–c

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4

Dvoynikov, Mikhail V., Dmitry I. Sidorkin, Andrey A. Kunshin, and Danil A. Kovalev. "Development of Hydraulic Turbodrills for Deep Well Drilling." Applied Sciences 11, no. 16 (2021): 7517. http://dx.doi.org/10.3390/app11167517.

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The article discusses the possibility of improving the design of the turbine of a hydraulic drilling machine for drilling wells in very hard rocks and at considerable depths (5000–12,000 m). The analysis of the results of studies on the technical and technological characteristics of downhole drilling motors showed that it is impossible to ensure stable operation due to the limitation on the operating temperature, while with an increase in the flow rate of the drilling fluid, they do not provide the required power on the spindle shaft, and cannot reach high-speed drilling. In such conditions, t

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5

Huan, Xiaolin, Gao Xu, Yi Zhang, Feng Sun, and Shifeng Xue. "Study on Thermo-Hydro-Mechanical Coupling and the Stability of a Geothermal Wellbore Structure." Energies 14, no. 3 (2021): 649. http://dx.doi.org/10.3390/en14030649.

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For processes such as water injection in deep geothermal production, heat transfer and fluid flow are coupled and affect one another, which leads to numerous challenges in wellbore structure safety. Due to complicated wellbore structures, consisting of casing, cement sheaths, and formations under high temperature, pressure, and in situ stress, the effects of thermo-hydro-mechanical (THM) coupling are crucial for the instability control of geothermal wellbores. A THM-coupled model was developed to describe the thermal, fluid, and mechanical behavior of the casing, cement sheath, and geological

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6

LaGrone, C. C., S. A. Baumgartner, and R. A. Woodroof. "Chemical Evolution of a High- Temperature Fracturing Fluid." Society of Petroleum Engineers Journal 25, no. 05 (1985): 623–28. http://dx.doi.org/10.2118/11794-pa.

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Abstract Reservoirs with bottomhole temperatures (BHT's) in excess of 250 deg. F [121 deg. C] and permeabilities of less than 1.0 md are commonly encountered in drilling and completing geothermal and deep gas wells. Successful stimulation of these wells often requires the use of massive hydraulic fracturing (MHF) treatments. Fracturing fluids chosen for these large treatments must possess shear and thermal stability at high BHT'S. The use of conventional fracturing fluids has been limited traditionally to wells with BHT's of 250 deg. F [121 deg. C] or less. Above 250 deg. F [121 deg. C], high

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7

Figueiredo, Bruno, Chin-Fu Tsang, and Auli Niemi. "The Influence of Coupled Thermomechanical Processes on the Pressure and Temperature due to Cold Water Injection into Multiple Fracture Zones in Deep Rock Formation." Geofluids 2020 (January 6, 2020): 1–14. http://dx.doi.org/10.1155/2020/8947258.

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A technique to produce geothermal energy from deep rock formations at elevated temperatures consists of drilling two parallel deep boreholes, the second of which is directed so as to intersect a series of fractures produced by hydraulic fracturing in the first borehole. Then, the first borehole is used for injection of cold water and the second used to produce water that has been heated by the deep rock formation. Some very useful analytical solutions have been applied for a quick estimate of the water outlet temperature and injection/production pressures in this enhanced geothermal system (EG

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8

Zhi, Zhang, Tai Ping Xiao, and Jian Hong Fu. "Study on Well-Kill Calculation Model with Deep-Water Engineer’s Method." Advanced Materials Research 393-395 (November 2011): 996–99. http://dx.doi.org/10.4028/www.scientific.net/amr.393-395.996.

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With the growing demand for oil and gas resources of China, exploration and development face more complex situation and there is an urgent need to move to (deeper than 1000m) deep sea oil and gas exploration and development. As the density window for safe drilling fluid is narrow, the mud line is in high pressure and low temperature environment, and the cycle pressure loss in choker line is larger and other characteristics, Well-kill calculation model with deep-water engineer’s method is disparate with that for land. To this end, combined with the special formation conditions in deep water wel

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9

Wachowicz-Pyzik, Anna, Anna Sowiżdżał, and Leszek Pająk. "Prediction of capacity of geothermal doublet located in the vicinity of Kalisz using the numerical modeling." E3S Web of Conferences 49 (2018): 00123. http://dx.doi.org/10.1051/e3sconf/20184900123.

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Attaining the proper values of main production parameters of operating geothermal installation: outflow, temperature, water level in production well and required injection pressure in a well for reinjection may significantly reduce the costs of energy production. Lower production costs compensate high investment expenditures and reduce the energy prices down to an acceptable level, competitive in relation to conventional energy sources. In the research project, we used the TOUGH2 simulator to select configuration of geothermal doublet and to estimate the discharge of potential geothermal insta

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10

Miecznik, Maciej, Anna Sowiżdżał, Barbara Tomaszewska, and Leszek Pająk. "Modelling geothermal conditions in part of the Szczecin Trough – the Chociwel area." Geologos 21, no. 3 (2015): 187–96. http://dx.doi.org/10.1515/logos-2015-0013.

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Abstract The Chociwel region is part of the Szczecin Trough and constitutes the northeastern segment of the extended Szczecin-Gorzów Synclinorium. Lower Jurassic reservoirs of high permeability of up to 1145 mD can discharge geothermal waters with a rate exceeding 250 m3/h and temperatures reach over 90°C in the lowermost part of the reservoirs. These conditions provide an opportunity to generate electricity from heat accumulated in geothermal waters using binary ORC (Organic Rankine Cycle) systems. A numerical model of the natural state and exploitation conditions was created for the Chociwel

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11

Zhou, Aizhao, Xianwen Huang, Wei Wang, Pengming Jiang, and Xinwei Li. "Thermo-Hydraulic Performance of U-Tube Borehole Heat Exchanger with Different Cross-Sections." Sustainability 13, no. 6 (2021): 3255. http://dx.doi.org/10.3390/su13063255.

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For reducing the initial GSHP investment, the heat transfer efficiency of the borehole heat exchange (BHE) system can be enhanced to reduce the number or depth of drilling. This paper proposes a novel and simple BHE design by changing the cross-sectional shape of the U-tube to increase the heat transfer efficiency of BHEs. Specifically, in this study, we (1) verified the reliability of the three-dimensional numerical model based on the thermal response test (TRT) and (2) compared the inlet and outlet temperatures of the different U-tubes at 48 h under the premise of constant leg distance and f

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12

Khudaiberdiev, Aziz, and Petr Kosianov. "Integrated physical enhanced recovery method for high-viscosity oil reservoirs." E3S Web of Conferences 244 (2021): 09012. http://dx.doi.org/10.1051/e3sconf/202124409012.

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The physical methods of enhanced oil recovery using electromagnetic fields are studied in this paper. Purpose of the work is to study the dependence of the main quantities that determine the volume of filtered oil, including the viscosity of oil, on the parameters (temperature, intensity and frequency) of thermal and electromagnetic fields, and optimize these parameters for maximum oil recovery factor using electric fields and steam treatment of the formation.It is proposed to combine the most effective and environmentally friendly methods to increase oil production. In the developed technique

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13

Geertsma, J. "Some Rock-Mechanical Aspects of Oil and Gas Well Completions." Society of Petroleum Engineers Journal 25, no. 06 (1985): 848–56. http://dx.doi.org/10.2118/8073-pa.

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Abstract Elementary borehole- and perforation-stability problems in friable clastic formations for unrestricted fluid flow between reservoir rock and underground opening are treated on the basis of linear poroelastic theory. Thermal stress effects caused by a temperature difference between reservoir and borehole fluids can be predicted from the mathematical similarity of poro- and thermoelasticity. A tension-failure condition applies for the prediction of hydraulic fracture initiation in a formation around injection wells. The resulting equations are partially well-known. Similarly, a uniaxial

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14

Hannun, Rafid M. Hannun, Mohammed H. Khalaf Khalaf, and Amel Hashim Husain Husain. "Solar Chimney and Power Tower Techniques for Power Production in Nasiriya City." Journal of Petroleum Research and Studies 8, no. 1 (2021): 77–92. http://dx.doi.org/10.52716/jprs.v8i1.219.

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The solar chimney and power tower are two of modern promised energy which can develop bylow losses, simplicity and high power.In this paper, the solar chimney and fossil fuel power tower parameters are studied by usingtheoretical equations in computational fluid dynamics CFD that substituted in some computerprograms such as MATLAP and FLUENT codes with additional related expressions. Fivedifferent models are used in this paper (Chimney height is: 12, 15, 20, 25, and 35 meter),(Diameter of collector base is: 5, 8, 10, 15, and 20 meter). The effect of inlet collector height,collector absorbabili

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15

Xu, Shiguang, Junjie Ba, Xianfeng Chen, Ting Zheng, Yaochi Yang, and Liang Guo. "Predicting Strata Temperature Distribution from Drilling Fluid Temperature." International Journal of Heat and Technology 34, no. 2 (2016): 345–50. http://dx.doi.org/10.18280/ijht.340227.

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16

Kozhevnykov, A. O., A. Yu Dreus, Liu Baochang, and A. K. Sudakov. "Drilling fluid circulation rate influence on the contact temperature during borehole drilling." Scientific Bulletin of National Mining University 1 (2018): 35–42. http://dx.doi.org/10.29202/nvngu/2018-1/14.

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17

JPT staff, _. "Temperature and Pressure Effects on Drilling-Fluid Rheology." Journal of Petroleum Technology 49, no. 11 (1997): 1212–13. http://dx.doi.org/10.2118/1197-1212-jpt.

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18

Talalay, Pavel, Zhengyi Hu, Huiwen Xu, et al. "Environmental considerations of low-temperature drilling fluids." Annals of Glaciology 55, no. 65 (2014): 31–40. http://dx.doi.org/10.3189/2014aog65a226.

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AbstractThe introduction of low-temperature fluid into boreholes drilled in ice sheets helps to remove drilling cuttings and to prevent borehole closure through visco-plastic deformation. Only special fluids, or mixtures of fluids, can satisfy the very strict criteria for deep drilling in cold ice. The effects of drilling fluid on the natural environment are analyzed from the following points of view: (1) occupational safety and health; (2) ozone depletion and global warming; (3) chemical pollution; and (4) biological pollution. Traditional low-temperature drilling fluids (kerosene-based fluid

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19

Yue, Qian Sheng, Qing Zhi Yang, Shu Jie Liu, Bao Sheng He, and You Lin Hu. "Rheological Properties of Water Based Drilling Fluid in Deep Water Drilling Conditions." Applied Mechanics and Materials 318 (May 2013): 507–12. http://dx.doi.org/10.4028/www.scientific.net/amm.318.507.

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The rheological property of the drilling fluid was one of the focus problems in deep-water drilling, which was widely concerned. In the article, the viscosity-temperature properties of commonly used water soluble polymeric solution, polymeric brine solution, bentonite slurry, polyacrylamide-potassium chloride drilling fluid with different densities and water-base drilling fluid systems commonly used for China offshore well drillings were studied. 4°C-to-20°C viscosity ratio and 4°C-to-20°C YP ratio were used to judge the thickening level of drilling fluids due to low temperature. The experimen

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20

Ribeiro, F. B., and V. M. Hamza. "Stabilization of bottom‐hole temperature in the presence of formation fluid flows." GEOPHYSICS 51, no. 2 (1986): 410–13. http://dx.doi.org/10.1190/1.1442099.

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Reliable estimates of bottom‐hole temperature (BHT) in oil wells are of considerable interest in reservoir engineering problems as well as in geothermal research. Because BHT measurements are usually made soon after drilling, true formation temperature can be obtained only by correcting for the effects of drilling disturbances. The magnitude of drilling disturbance depends upon duration of drilling, time elapsed after stoppage of drilling, well characteristics, thermal properties of drilling fluid, and the nature of heat exchange between the well and the formation.

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21

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 lo

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22

Li, Jun, Tao Huang, De Wei Gao, Chao Wang, Xue Feng Song, and Kai Ren. "Erosion Law of Inner Drill Pipe in Reelwell Reverse Circulation Directional Drilling." Materials Science Forum 944 (January 2019): 1061–66. http://dx.doi.org/10.4028/www.scientific.net/msf.944.1061.

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In the process of ReelWell reverse circulation directional drilling, the drilling fluid returns through the inner drill pipe, and the debris particles continuously eroded and wear the drill pipe in the inclined section, which easily causes the failure of the inner drill pipe erosion. Analysis, through the Fluent software to simulate the flow field in the inner drill pipe, to study the impact of different drilling fluid displacement, different mechanical drilling speed, different cuttings particle size on the drill pipe erosion. The results show that: (1) The larger the drilling fluid displacem

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23

Guo, Li Ping, and Lei Wang. "Study on the Flow Behavior of Underbalanced Circulative Micro-Foam Drilling Fluid." Advanced Materials Research 706-708 (June 2013): 1585–88. http://dx.doi.org/10.4028/www.scientific.net/amr.706-708.1585.

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Underbalanced drilling is a new method for the exploratory development of low pressure and permeability reservoirs; circulative micro-foam drilling fluid is a new technology which is developed for realizing near-balanced drilling and underbalanced drilling. The flow behavior of circulative micro-foam drilling fluid in wellbore was researched by applying HPHT experiment apparatus. It is concluded that the flow behavior parameters of circulative micro-foam drilling fluid is only related to temperature but not to pressure; the constitutive equation accords with the rheological law of power-law fl

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24

Bybee, Karen. "Formate-Based Reservoir-Drilling Fluid Meets High-Temperature Challenges." Journal of Petroleum Technology 58, no. 11 (2006): 57–59. http://dx.doi.org/10.2118/1106-0057-jpt.

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25

Elward-Berry, Julianne, and J. B. Darby. "Rheologically Stable, Nontoxic, High-Temperature Water-Base Drilling Fluid." SPE Drilling & Completion 12, no. 03 (1997): 158–62. http://dx.doi.org/10.2118/24589-pa.

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26

JPT staff, _. "Modeling Effects of Drilling-Fluid Temperature on Wellbore Stability." Journal of Petroleum Technology 50, no. 11 (1998): 68–70. http://dx.doi.org/10.2118/1198-0068-jpt.

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27

Wang, Sheng, Zhihong Shu, Liyi Chen, et al. "Low temperature green nano-composite vegetable-gum drilling fluid." Applied Nanoscience 9, no. 7 (2019): 1579–91. http://dx.doi.org/10.1007/s13204-019-01033-1.

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28

Wang, Sheng, Zhijun Li, Qiang Chen, Ruhua Gong, Gan Zhao, and Liyi Chen. "Rectorite drilling fluid: high-temperature resistance for geothermal applications." Geothermics 96 (November 2021): 102196. http://dx.doi.org/10.1016/j.geothermics.2021.102196.

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29

Hou, Yali, Changhe Li, Hongliang Ma, Yanbin Zhang, Min Yang, and Xiaowei Zhang. "An Experimental Research on Bone Drilling Temperature in Orthopaedic Surgery." Open Materials Science Journal 9, no. 1 (2015): 178–88. http://dx.doi.org/10.2174/1874088x01509010178.

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The bone drilling temperature fields under different cutting parameters and cooling modes were experimental researched by using common twist drill, diamond punching pin, diamond bullet-like grinding head and diamond spherical grinding head. Three cooling modes were applied, namely, natural air cooling, normal saline pouring cooling and normal saline spray cooling. K-thermocouple was used to measure temperature in bone hole. Results showed that the drill shape could influence drilling temperature greatly. The maximum drilling temperature of diamond spherical grinding head is 46.31°C. The maximu

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30

Gao, Yonghai, Baojiang Sun, Boyue Xu, et al. "A Wellbore/Formation-Coupled Heat-Transfer Model in Deepwater Drilling and Its Application in the Prediction of Hydrate-Reservoir Dissociation." SPE Journal 22, no. 03 (2016): 756–66. http://dx.doi.org/10.2118/184398-pa.

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Summary On the basis of the wellbore and reservoir heat-transfer process during deepwater drilling, a heat-transfer model between wellbore and formation is built up for two different conditions: without riser and with riser. Wellbore and formation temperature distributions under different drilling-fluid-injection temperatures, flow rates, circulating times, and drilling depths are simulated by use of this model. Taking the hydrate-phase equilibrium into consideration, a possible region of hydrate-formation dissociation is analyzed, and effective methods are proposed to control the hydrate diss

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31

Liu, Jingping, Zhiwen Dai, Ke Xu, et al. "Water-Based Drilling Fluid Containing Bentonite/Poly(Sodium 4-Styrenesulfonate) Composite for Ultrahigh-Temperature Ultradeep Drilling and Its Field Performance." SPE Journal 25, no. 03 (2020): 1193–203. http://dx.doi.org/10.2118/199362-pa.

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Summary The rapidly increasing global oil/gas demand and gradual depletion of shallow reservoirs require the development of deep oil/gas reservoirs and geothermal reservoirs. However, deep drilling suffers from drilling-fluid failures under ultrahigh temperature, which cause serious accidents such as wellbore collapse, stuck pipe, and even blowouts. In this study, we revealed the role of polymeric additives in improving the ultrahigh-temperature tolerance of bentonite-based drilling fluids, aiming to provide practical and efficient solutions to the failure of drilling fluids in severe conditio

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32

Tang, Zhiqiang, Qian Li, and Hu Yin. "The near-wellbore pressure calculation model incorporating thermochemical effect." Thermal Science 22, no. 1 Part B (2018): 623–30. http://dx.doi.org/10.2298/tsci170329186t.

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The potential difference of hydraulic pressure, solute concentration and temperature between the drilling fluid and the formation fluid can induce the flow of solvent and cause changes in the pore pressure during drilling a tight formation, which may result in wellbore instability. According to the continuity equation of fluid, the pore pressure calculation model considering the effect of thermochemical coupling is established and the solution of the pore pressure in the Laplace domain is given. Using this model, the effects of the temperature, solute concentration and viscosity of drilling fl

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33

Wang, Nan Nan, Yong Ping Wang, Dong Zhang, and Hui Min Tang. "Micro Foam Drilling Fluid System Performance Research and Application." Advanced Materials Research 868 (December 2013): 601–5. http://dx.doi.org/10.4028/www.scientific.net/amr.868.601.

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Micro foam drilling fluid has irreplaceable advantages in reservoir protection, drilling speed, improve the cementing quality and leak plugging, especially suitable for the "three low" Daqing peripheral oilfield Haita area. Indoor the foaming agent, foam stabilizing agent were screened, Preferably choose the efficient composite foaming agent, stabilizer and thickener, the drilling fluid system is transformed into micro foam drilling fluid system. And evaluate the inhibition, anti temperature, anti pollution (anti clay, calcium, anti kerosene) reservoir protection capability, The micro foam dri

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34

Wang, Ping Quan, Yang Bai, Gang Peng, and Zhi Wei Qian. "Drilling Fluid Development and Performance Evaluation of Deep and Ultra-Deep High-Density Saturated Brine." Advanced Materials Research 524-527 (May 2012): 1382–88. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1382.

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Due to the high temperature , great pressure and complex lithology of super-deep well bottom, there exist such problems such as high solid concentration, multiple but inaccurate treating chemicals, complex formulation with instability of drilling fluid system, resulting in a frequent occurrence of underground complex accident and a waste of a lot of manpower and material resources. Therefore, based on the analysis of performance factors of ultra-deep drilling fluid system, the approach of regulating water based drilling fluid properties of super-deep well has been found. Moreover, through scre

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35

Li, Yang, Yuanfang Cheng, Chuanliang Yan, Lifang Song, Xiaohui Zhou, and Chengcheng Niu. "Influence of drilling fluid temperature on borehole shrinkage during drilling operation in cold regions." Journal of Petroleum Science and Engineering 190 (July 2020): 107050. http://dx.doi.org/10.1016/j.petrol.2020.107050.

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36

Meng, Fanhe, Aiguo Yao, and Shuwei Dong. "Prediction of Wellbore Temperatures During the Scientific Ultra-Deep Drilling Process." Open Petroleum Engineering Journal 8, no. 1 (2015): 451–56. http://dx.doi.org/10.2174/1874834101508010451.

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In order to carry out a series of key basic researches, a scientific ultra-deep drilling plan is being undertaken in China. Wellbore temperature is one of the key factors during the drilling process. In this paper, we established a twodimensional transient numerical model to predict the ultra-deep wellbore temperature distributions during circulation and shut-in stages. The simulation results indicate that the cooling effect of drilling fluid circulation is very obvious, especially during the inception phase. Drilling fluid viscosity has great influence on the temperature distributions during

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37

Li, Ben, Hui Li, Boyun Guo, Xiao Cai, and Mas lwan Konggidinata. "A New Numerical Solution To Predict the Temperature Profile of Gas-Hydrate-Well Drilling." SPE Journal 22, no. 04 (2017): 1201–12. http://dx.doi.org/10.2118/185177-pa.

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Summary Gas-hydrate cuttings are conveyed upward by the drilling fluid through the outer drillpipe/wellbore annulus during the gas-hydrate-well-drilling process. The temperature profile along the wellbore during the drilling process has not been thoroughly investigated because the gas-hydrate cuttings could affect the temperature of the drilling fluid along the wellbore. As the mixture of drilling fluid and gas hydrates flows from the bottom to the surface, the methane and other hydrocarbons present in the gas hydrates would change from liquid to gas phase and further cause well-control issues

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38

Loginov, V. S., and V. G. Milyutin. "TEMPERATURE FIELDS IN THE WELL AT THE SWITCHED-OFF CIRCULATION OF DRILLING FLUID." Oil and Gas Studies, no. 5 (November 1, 2017): 75–80. http://dx.doi.org/10.31660/0445-0108-2017-5-75-80.

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The thermal model of the well after switching off the flow of drilling mud is considered. The received results are auxiliary for formulation of the general model. The general model in conjunction with temperature data of drilling mud on a surface will allow to reveal layers of the hydrocarbons, penetrated earlier with drilling.

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39

Hou, Yali, Changhe Li, Hongliang Ma, Yanbin Zhang, Min Yang, and Xiaowei Zhang. "A Theoretical Analysis on Bone Drilling Temperature Field of Superhard Drill." Open Mechanical Engineering Journal 10, no. 1 (2016): 109–25. http://dx.doi.org/10.2174/1874155x01610010109.

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To overcome strong drilling force and over high temperature during orthopedic surgery, the four medical drills with different geometrical shapes by using superhard materials were designed. The bone drilling temperature field of superhard drill was theoretical analyzed. Results showed that brazed step drill has the most ideal drilling temperature. It controls the maximum bone temperature below 47°C even under dry drilling. The maximum bone temperature of brazed twist drill is a little higher than 47°C. With appropriate cooling method, brazed twist drill also could provide ideal effect. On the c

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40

Dong, Pu, Ren, Zhai, Gao, and Xie. "Thermoresponsive Bentonite for Water-Based Drilling Fluids." Materials 12, no. 13 (2019): 2115. http://dx.doi.org/10.3390/ma12132115.

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As an important industrial material, bentonite has been widely applied in water-based drilling fluids to create mud cakes to protect boreholes. However, the common mud cake is porous, and it is difficult to reduce the filtration of a drilling fluid at high temperature. Therefore, this paper endowed bentonite with a thermo response via the insertion of N-isopropylacrylamide (NIPAM) monomers. The interaction between NIPAM monomers and bentonite was investigated via Fourier infrared spectroscopy (FTIR), isothermal adsorption, and X-ray diffraction (XRD) at various temperatures. The results demons

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41

Quan, Hongping, Huan Li, Zhiyu Huang, Tailiang Zhang, and Shanshan Dai. "Copolymer SJ-1 as a Fluid Loss Additive for Drilling Fluid with High Content of Salt and Calcium." International Journal of Polymer Science 2014 (2014): 1–7. http://dx.doi.org/10.1155/2014/201301.

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A ternary copolymer of 2-acrylamide-2-methyl propane sulfonic acid (AMPS), acrylamide (AM), and allyl alcohol polyoxyethylene ether (APEG) with a side chain polyoxyethylene ether(C2H4O)nSJ-1 were designed and synthesized in this work. Good temperature resistance and salt tolerance of “–SO3-” of AMPS, strong absorption ability of “amino-group” of AM, and good hydrability of side chain polyoxyethylene ether(C2H4O)nof APEG provide SJ-1 excellent properties as a fluid loss additive. The chemical structure of ternary copolymer was characterized by Fourier transform infrared (FTIR) spectroscopy. The

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Elkatatny, Salaheldin. "Enhancing the Stability of Invert Emulsion Drilling Fluid for Drilling in High-Pressure High-Temperature Conditions." Energies 11, no. 9 (2018): 2393. http://dx.doi.org/10.3390/en11092393.

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Drilling in high-pressure high-temperature (HPHT) conditions is a challenging task. The drilling fluid should be designed to provide high density and stable rheological properties. Barite is the most common weighting material used to adjust the required fluid density. Barite settling, or sag, is a common issue in drilling HPHT wells. Barite sagging may cause many problems such as density variations, well-control problems, stuck pipe, downhole drilling fluid losses, or induced wellbore instability. This study assesses the effect of using a new copolymer (based on styrene and acrylic monomers) o

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Zhang, Jie, Gang Chen, and Nai Wang Yang. "Development of a New Drilling Fluid Additive from Lignosulfonate." Advanced Materials Research 524-527 (May 2012): 1157–60. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1157.

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Nitration-oxidation lignosulfonate (NOLS) was prepared using lignosulfonate (LS) as raw material. The product was characterized by Fourier Transform Infrared spectroscopy (FT-IR). The performance as a drilling fluid additive was evaluated with regard to rhology, filtration and temperature resistance. The results showed that NOLS can improve the viscosity under room temperature, decrease the viscosity under high temperature and reduce the filtration more effectively than that of lignosulfonate, which display its good temperature resistance. So NOLS may be used as sustained release nitrogen fert

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Thaemlitz, C. J., A. D. Patel, George Coffin, and Lee Conn. "New Environmentally Safe High-Temperature Water-Based Drilling-Fluid System." SPE Drilling & Completion 14, no. 03 (1999): 185–89. http://dx.doi.org/10.2118/57715-pa.

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Zhang, Hongyun, Deli Gao, Saeed Salehi, and Boyun Guo. "Effect of Fluid Temperature on Rock Failure in Borehole Drilling." Journal of Engineering Mechanics 140, no. 1 (2014): 82–90. http://dx.doi.org/10.1061/(asce)em.1943-7889.0000648.

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Zhang, Yanna, Huaidong Luo, Libao Shi, and Hongjun Huang. "Synthesis of high-temperature viscosity stabilizer used in drilling fluid." IOP Conference Series: Earth and Environmental Science 121 (February 2018): 052029. http://dx.doi.org/10.1088/1755-1315/121/5/052029.

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Falih, Ghufran Falih, Asawer A. Alwasiti Alwasiti, and Nada S. Alzubaidi Alzubaidi. "Improving the Performance of Drilling Fluid Using MgO Nano Particles." Journal of Petroleum Research and Studies 8, no. 3 (2021): 179–93. http://dx.doi.org/10.52716/jprs.v8i3.278.

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One of the most important factors that cause formation damage is drilling fluidinvasion caused by mud filtration. Hence, it is essential to minimize the mud filtration inorder to reduce its damage to the formation using drilling fluid additives that control andminimize the filtration rate. Magnesium Oxide (MgO) nanoparticles at different masses(0.01, 0.05, 0.07, 0.1, and 0.2) gm with water base mud have been investigated in thisresearch to measure its effect on the filtration rate. Four types of drilling fluid are used inthis research; API water base mud WBM, Saturated salt water mud, DURA THE

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Wheat, C. Geoffrey, Christopher Kitts, Camden Webb, et al. "A new high-temperature borehole fluid sampler: the Multi-Temperature Fluid Sampler." Scientific Drilling 28 (December 1, 2020): 43–48. http://dx.doi.org/10.5194/sd-28-43-2020.

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Abstract. Deep (>1 km depth) scientific boreholes are unique assets that can be used to address a variety of microbiological, hydrologic, and biogeochemical hypotheses. Few of these deep boreholes exist in oceanic crust. One of them, Deep Sea Drilling Project Hole 504B, reaches ∼190 ∘C at its base. We designed, fabricated, and laboratory-tested the Multi-Temperature Fluid Sampler (MTFS), a non-gas-tight, titanium syringe-style fluid sampler for borehole applications that is tolerant of such high temperatures. Each of the 12 MTFS units collects a single 1 L sample at a predetermined temperat

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Jiang, Xiao Ling, Zong Ming Lei, and Kai Wei. "Application of R/S Rheometer in Low Temperature Drilling Fluid Rheology Determination." Advanced Materials Research 490-495 (March 2012): 3114–18. http://dx.doi.org/10.4028/www.scientific.net/amr.490-495.3114.

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With six-speed rotary viscometer measuring the rheology of drilling fluid at low temperature, during the high-speed process, the drilling fluid temperature is not constant at low temperature, which leads to the inaccuracy in rheological measurement. When R/S rheometer is used cooperating with constant low-temperature box , the temperature remains stable during the process of determining the drilling fluid rheology under low temperature. The R/S rheometer and the six-speed rotational viscometer are both coaxial rotational viscometers, but they work in different ways and the two cylindrical clea

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Song, Xun Cheng, Xiao Long Xu, Sha Sha Hu, and Zhi Chuan Guan. "Full Transient Features of Heat Transfer and Sensitivities on Deep Water Wells." Advanced Materials Research 524-527 (May 2012): 1423–28. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1423.

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Wellbore temperature is significant to well program and safety drilling for deep water drilling operations. On the basis of transient heat transfer mechanisms involved in deep water drilling among wellbore and formation and sea water, wellbore temperature profile, especially near sea bed and sensitivities to drilling fluid circulating duration, inlet temperature, water depth, water temperature, riser insulation and drilling fluid specific heat capacity have been analyzed via this model. Analysis show that deep-water wellbore temperature is much lower than a land well, the temperatures above se

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