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Journal articles on the topic 'Drilling Fluid Aging'

Author: Grafiati

Published: 4 June 2021

Last updated: 19 February 2022

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1

Ismail, Abdul Razak, Wan Rosli Wan Sulaiman, Mohd Zaidi Jaafar, Issham Ismail, and Elisabet Sabu Hera. "Nanoparticles Performance as Fluid Loss Additives in Water Based Drilling Fluids." Materials Science Forum 864 (August 2016): 189–93. http://dx.doi.org/10.4028/www.scientific.net/msf.864.189.

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Nanoparticles are used to study the rheological characteristics of drilling fluids. Nanoparticles have high surface to volume ratio, therefore only small quantity is required to blend in the drilling fluid. This research evaluates the performance of nanosilica and multi walled carbon nanotubes (MWCNT) as fluid loss additives in water based drilling fluid with various nanoparticles concentration and temperature. The results show that plastic viscosity, yield point and gel strength of drilling fluid increases as the concentration of nanoparticles increased. Drilling fluid with nanosilica gives t

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2

Sulaiman, Nada M., and Nada S. Al-Zubaidi. "The Performance of Iraqi Palygorskite in Salt Drilling Fluid." Association of Arab Universities Journal of Engineering Sciences 27, no. 1 (2020): 74–82. http://dx.doi.org/10.33261/jaaru.2019.27.1.009.

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In drilling fluid program, selecting the drilling fluid that will reduce the lost time is the first objective, and will be economical regardless of its cost. The amount and type of solids in drilling fluid is the primary control of the rheological and filtration properties. Palygorskite clay (attapulgite) is an active solid that has ability to reactive with its environment and form a gel structure within a fluid and due to its stability in the presence of brines and electrolytes this type of clay is preferred for use. The aim of this study is to calculate the yield of clay for both types of lo

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3

Li, Zhijun, Xiaolin Pu, Huaizhi Tao, Lu Liu, and Junlin Su. "Synthesis and properties of acrylamide 2-acrylamido-2-methypropane sulfonic acid sodium styrene sulfonate N-vinyl pyrrolidone quadripolymer and its reduction of drilling fluid filtration at high temperature and high salinity." Journal of Polymer Engineering 34, no. 2 (2014): 125–31. http://dx.doi.org/10.1515/polyeng-2013-0257.

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Abstract Acrylamide (AM), 2-acrylamido-2-methypropane sulfonic acid, sodium styrene sulfonate (SSS), and N-vinyl pyrrolidone (NVP) monomers were copolymerized via a redox initiator system to synthesize a quadripolymer capable of reducing drilling fluid filtration. Fourier transform infrared spectroscopy (FT-IR) was used to determine the molecular structure of the product, confirming its successful synthesis. The effects of the copolymer on the properties and salt resistance of drilling fluid are discussed. The adsorption of the copolymer on bentonite was also studied using atomic force microsc

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4

Jha*, Dr Praveen Kumar, Dr Vinod Kumar Saxena, Prof Suresh Kumar Yatirajula, and Dr Ayanagounder Kumar. "Impact of Natural Polymer (Xanthan Gum) and Bentonite Clay on the Development of Oil-In-Water (O/W) Emulsion Drilling Fluids." International Journal of Innovative Technology and Exploring Engineering 10, no. 10 (2021): 129–36. http://dx.doi.org/10.35940/ijitee.i9344.08101021.

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Drilling fluid plays the same role in oil and gas well drilling as the blood in human body. A new type of oil-in-water (o/w) emulsion drilling fluid has been developed using diesel oil as dispersed phase, brine water as continuous phase, xanthan gum as viscosity modifier and clay as emulsion stabilizer and filtration controlling agent. Initially, standard recommended techniques were opted to detect the rheological properties of the emulsions. The fluids have also shown stable properties upto 70°C after aging for 24 h. As drilling fluids encounter a lot of variation in temperature and pressure

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5

Mansoor, Hameed Hussain Ahmed, Srinivasa Reddy Devarapu, Robello Samuel, Tushar Sharma, and Swaminathan Ponmani. "Experimental Investigation of Aloe-Vera-Based CuO Nanofluid as a Novel Additive in Improving the Rheological and Filtration Properties of Water-Based Drilling Fluid." SPE Drilling & Completion 36, no. 03 (2021): 542–51. http://dx.doi.org/10.2118/205004-pa.

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Summary Drilling technology in petroleum engineering is associated with problems such as high fluid loss, poor hole cleaning, and pipe sticking. Improvement of rheological and filtration properties of water-based drilling fluids (WDFs) plays a major role in resolving these drilling problems. The application of nanotechnology to WDF in the recent past has attracted much attention in addressing these drilling operations problems. In the present work, we investigate the application of natural aloe vera and CuO nanofluids combined as an additive in WDF to address the drilling problems. The nanoflu

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6

Heidarian, Javad. "Aging of carbon nanotube-filled fluoroelastomer in oil-based drilling fluid." Polimery 63, no. 03 (2018): 191–212. http://dx.doi.org/10.14314/polimery.2018.3.4.

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7

Tan, Xianfeng, Longchen Duan, Weichao Han, Ying Li, and Mingyi Guo. "A Zwitterionic Copolymer as Rheology Modifier and Fluid Loss Agents for Water-Based Drilling Fluids." Polymers 13, no. 18 (2021): 3120. http://dx.doi.org/10.3390/polym13183120.

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To overcome the negative impact on the rheological and filtration loss properties of drilling fluids caused by elevated temperature and salts contamination, which are common in ultradeep or geothermal drilling operations, it is imperative to develop highly efficient additives used in the water-based drilling fluid. In this study, a zwitterionic copolymer P (AM/DMC/AMPS/DMAM, ADAD) was synthesized by using acrylamide (AM), cationic monomer methacrylatoethyl trimethyl ammonium chloride (DMC), anionic monomer 2-acrylamide-2-methyl propane sulfonic acid (AMPS), and N,N-dimethylacrylamide (DMAM) th

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8

Wang, Fu Hua, Rui He Wang, and Xue Chao Tan. "Study on Multi-Functional Experimental Apparatus for the Performance Evaluation of HTHP Drilling Fluid." Advanced Materials Research 422 (December 2011): 10–16. http://dx.doi.org/10.4028/www.scientific.net/amr.422.10.

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With the development of deep well drilling technology, a new HTHP (High Temperature High Pressure) experimental apparatus LH-1 was developed to meet the need of research and evaluation of deep well drilling fluid. With the advanced dynamic seal technology, mechanical transmission and data sensing technology, this new apparatus has many kinds of HTHP testing functions in a body and could evaluate manifold performances at the dynamic state of high temperature and high pressure including HTHP dynamic or static filtration test, high temperature dynamic scattering test of drilling cuttings, HTHP dy

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9

LONG, WEIJUN, HUIZE LEO, ZHEN YAN, et al. "Synthesis of filtrate reducer from biogas residue and its application in drilling fluid." March 2020 19, no. 3 (2020): 151–58. http://dx.doi.org/10.32964/tj19.3.151.

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Biogas residues (BR) containing cellulose and lignin are produced with the rapid development of biogas engineering. BR can be used to prepare the filtrate reducer of water-based drilling fluid in oilfields by chemi-cal modification. BR from anaerobically fermenting grain stillage was alkalized and etherified by caustic soda and chloroacetic acid to prepare filtrate reducer, which was named as FBR. The long-chain crystalline polysaccharides were selected as dispersing agents (DA), and the water-soluble silicate was used as the cross-linking agent. After the hot rolling of FBR in saturated saltw

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10

Gautam, Sidharth, and Chandan Guria. "Optimal Synthesis, Characterization, and Performance Evaluation of High-Pressure High-Temperature Polymer-Based Drilling Fluid: The Effect of Viscoelasticity on Cutting Transport, Filtration Loss, and Lubricity." SPE Journal 25, no. 03 (2020): 1333–50. http://dx.doi.org/10.2118/200487-pa.

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Summary Viscoelasticity plays a significant role in improving the performance of the drilling fluid by manipulating its elastic properties. An appropriate value of the first normal stress difference (N1), extensional viscosity (ηe), and relaxation time (θ) enhance the cutting transportability, hole-cleaning ability, filtration loss, and lubrication behavior. However, the performance of the drilling fluid deteriorates during the drilling of high-pressure and high-temperature (HPHT) wells under acid gas and salt(s) contamination. Therefore, it is a challenging task to synthesize a thermally and

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11

Bazzine, Zineb, Abdelmadjid Dobbi, Hamid Lebtahi, and Ahmed Ali Zerrouki. "Alteration effect on petrophysical properties of reservoirs rocks by drilling fluid emulsifiers." Journal of Petroleum Exploration and Production Technology 11, no. 8 (2021): 3203–12. http://dx.doi.org/10.1007/s13202-021-01241-y.

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AbstractSurfactants formulated into oil-based mud can adsorb to pore surfaces causing changes in rock wettability, which are widely believed to impair formation permeability when oil-based mud invades the near-wellbore region. In the present study, the effects of oil-based mud with Versawet and Versacoat surfactants, on the petrophysical properties and wettability of drilling cutting samples from sandstone reservoirs were investigated through relative permeability, wettability index, and adsorption measurements at standard conditions in a micromodel device. The X-ray analysis and flame photome

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12

SINGH, PRAMOD KUMAR, and V. P. SHARMA. "Effect of Additives and Aging on the Rheological Properties of Water-Based Drilling Fluid." Energy Sources 13, no. 3 (1991): 369–87. http://dx.doi.org/10.1080/00908319108908995.

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13

Dong, Liming. "An Enhanced Crack-Plugging and Pressure-Bearing Oil-Based Drilling Fluid System." Environmental and Earth Sciences Research Journal 7, no. 4 (2020): 164–68. http://dx.doi.org/10.18280/eesrj.070406.

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Compared with water-based drilling fluids (WBDF), oil-based drilling fluids (OBDF) are more prone to borehole leakage loss. Once borehole leakage occurs, it’s difficult to handle the leakage site and it will inevitably cause great economic losses. To cope with the major difficulties in OBDF leakage-proof and crack plugging, this paper conducted experiments on an enhanced crack-plugging and pressure-bearing OBDF system starting from the borehole leakage prevention measures. Then, by selecting and optimizing the materials of leakage-proof agent and crack-plugging agent for OBDF, this study prepa

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14

Su, Junlin, Qi Chu, and Mao Ren. "Properties of high temperature resistance and salt tolerance drilling fluids incorporating acrylamide/2-acrylamido-2-methyl-1-propane sulfonic acid/N-vinylpyrrolidone/dimethyl diallyl ammonium chloride quadripolymer as fluid loss additives." Journal of Polymer Engineering 34, no. 2 (2014): 153–59. http://dx.doi.org/10.1515/polyeng-2013-0270.

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Abstract A quadripolymer of acrylamide (AM), 2-acrylamido-2-methyl-1-propane sulfonic acid (AMPS), N-vinylpyrrolidone (NVP) and dimethyl diallyl ammonium chloride (DMDAAC) was synthesized by solution free radical polymerization, and characterized using Fourier transform infrared (FTIR), gel permeation chromatography (GPC) and thermogravimetric analysis (TGA) methods. The rheological and filtrate properties of saturated brine-based fluid with AM/AMPS/NVP/DMDAAC quadripolymer were investigated before and after thermal aging tests. The apparent viscosity (AV), plastic viscosity (PV) and yield poi

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15

Zou, Zhifei, Qingcheng Zhao, Qingying Wang, and Fengshan Zhou. "Thermal stability of xanthan gum biopolymer and its application in salt-tolerant bentonite water-based mud." Journal of Polymer Engineering 39, no. 6 (2019): 501–7. http://dx.doi.org/10.1515/polyeng-2018-0386.

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Abstract Xanthan gum from Xanthomona campestris (XC) is a chain-like polysaccharide biopolymer with good salt tolerance. The temperature resistance of XC seriously affects its application in drilling fluids. Results have shown that when the temperature of the XC solution rose to 120°C, after several hours the shear stress of the XC solution was almost 0 mPa · s at different shear rates. In this study, the molecular structure of XC was enhanced by crosslinking with chromic oxalate and borax and then adding sodium sulfite to further enhance the temperature resistance of the gum. Selected materia

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16

Soto, Diana, Orietta León, José Urdaneta, Alexandra Muñoz-Bonilla, and Marta Fernández-García. "Modified Starch as a Filter Controller in Water-Based Drilling Fluids." Materials 13, no. 12 (2020): 2794. http://dx.doi.org/10.3390/ma13122794.

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Herein, the effectiveness of an itaconic acid (IA) graft copolymer on native corn starch (NCS) as a filter control agent in fresh water-based drilling fluids (WBDFs) was evaluated. The copolymer (S-g-IA_APS) was synthesized by conventional radical dispersion polymerization using the redox initiation system (NH4)2S2O8/NaHSO3. The modification of the starches was verified by volumetry, Fourier transform infrared spectroscopy (FTIR), thermogravimetric analysis (TGA), and scanning electron microscopy (SEM). Then, three WBDFs were formulated in which only the added polymer (NCS, S-g-IA_APS, and a c

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17

Jasiński, Bartłomiej. "Analiza możliwości podwyższenia stabilności termicznej płuczek wiertniczych poprzez dobór środków chemicznych." Nafta-Gaz 77, no. 3 (2021): 152–63. http://dx.doi.org/10.18668/ng.2021.03.02.

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Drilling deep holes or drilling to provide access to thermal waters places increasingly high demands on the properties of the drilling muds. Due to the very high temperature, it may be difficult to maintain the appropriate rheology of the drilling fluid during drilling, especially when an inflow of highly mineralized brines occurs. High temperatures significantly reduce the effectiveness of most of the polymeric agents currently used in the drilling muds technology, in extreme cases causing complete and irreversible damage to their structure. Polymers with ether bonds, which include starches a

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18

Zhang, Jie, Gang Chen, Nai Wang Yang, and Yang Guang Wang. "Preparation and Evaluation of Sodium Hydroxymethyl Lignosulfonate as Eco-Friendly Drilling Fluid Additive." Advanced Materials Research 415-417 (December 2011): 629–32. http://dx.doi.org/10.4028/www.scientific.net/amr.415-417.629.

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Sodium hydroxymethyl lignosulfonate (NaHLS) was prepared by hydroxymethylation of sodium lignosulfonate (NaLS) and formaldehyde to enhance the performance as drilling fluids additive. The performances of the modified drilling fluid with NaLS and NaHLS, such as rheology behavior, filtration reducer and inhibitive ability were evaluated. The results indicate that the NaHLS can enhance the viscosity at low temperature, reduce the viscosity after ageing under 180 °C, which is more effective than that of NaLS. And NaHLS reduces the filtration, as the thickness of the modified fluid mud-cake is much

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19

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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20

Velazco, M. A., A. Bruce, M. Ferris, J. Reed, and R. Kandasamy. "The role of ferrous clays in the interpretation of wettability – a case study." E3S Web of Conferences 89 (2019): 03002. http://dx.doi.org/10.1051/e3sconf/20198903002.

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Clean sandstone, with minimal clay content, is expected to be strongly water wet once the rock has been through an effective cleaning process. Even samples containing significant clay minerals are usually expected to be water wet after appropriate cleaning. However, tests carried out on core samples from Fields in three different global locations show mixed indices, even for clean state samples where no aging with crude oil has taken place. A few hypotheses for this behaviour considered herein are: whether the cleaning method was adequate, whether wettability was altered by an external factor,

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21

Heidarian, Javad. "OH-functionalized carbon nanotube filled fluoroelastomers aging test in oil based drilling fluids." Journal of Petroleum Science and Engineering 158 (September 2017): 11–28. http://dx.doi.org/10.1016/j.petrol.2017.08.036.

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22

Heidarian, Javad. "Acid surface modified carbon nanotube-filled fluoroelastomers aging test in oil-based drilling fluids." Journal of Elastomers & Plastics 49, no. 8 (2017): 706–37. http://dx.doi.org/10.1177/0095244317695362.

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23

Beg, Mukarram, Pranav Kumar, Pratham Choudhary, and Shivanjali Sharma. "Effect of high temperature ageing on TiO2 nanoparticles enhanced drilling fluids: A rheological and filtration study." Upstream Oil and Gas Technology 5 (October 2020): 100019. http://dx.doi.org/10.1016/j.upstre.2020.100019.

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24

Huang, Weian, Yee-Kwong Leong, Ting Chen, Pek-Ing Au, Xianhua Liu, and Zhengsong Qiu. "Surface chemistry and rheological properties of API bentonite drilling fluid: pH effect, yield stress, zeta potential and ageing behaviour." Journal of Petroleum Science and Engineering 146 (October 2016): 561–69. http://dx.doi.org/10.1016/j.petrol.2016.07.016.

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25

Zhang, Rongjun, Yun Bai, Yan Sun, et al. "Preparation of Ammonium Oleic Acid Salts and Their Evaluation as Shale Swelling Inhibitors in Water-Based Drilling Fluid." Tenside Surfactants Detergents 58, no. 4 (2021): 311–16. http://dx.doi.org/10.1515/tsd-2019-2238.

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Abstract In this paper, ammonium oleic acid salts (AOS) were prepared from oleic acid and amines and investigated as low molecular weight shale swelling inhibitors. First, the inhibitory effect of AOS was investigated using the linear expansion test of bentonite. The results show that the inhibitor prepared from oleic acid and tetraethylene pentamine with a molar ratio of 1:2 (AOS-8) has an excellent inhibitory effect on the hydration expansion of bentonite. The inhibitory effect of AOS-8 on bentonite was further investigated in subsequent work steps using various methods, including the linear

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26

Ismail, Abdul Razak, W. R. W. Sulaiman, M. Z. Jaafar, A. Aftab, A. A. Razi, and Z. H. Ibupoto. "The application of MWCNT to enhance the rheological behavior of drilling fluids at high temperature." Malaysian Journal of Fundamental and Applied Sciences 12, no. 3 (2017). http://dx.doi.org/10.11113/mjfas.v12n3.423.

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Drilling fluid is the key component to drill oil and gas wells. The rheological behavior of drilling fluid will be affected when drilling deep wells especially at high temperature and high pressure reservoir. This research was conducted to study the effect of the nanoparticles over the rheological properties of the drilling fluid when aging at high temperature condition. Several drilling fluids were prepared using synthetic based fluids (Sarapar and Saraline) to study the effect of multi-walled carbon nanotube (MWCNT) at different concentrations. The rheological properties of drilling fluid we

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27

Alvi, Muhammad Awais Ashfaq, Mesfin Belayneh, Kjell Kåre Fjelde, Arild Saasen, and Sulalit Bandyopadhyay. "Effect of Hydrophobic Iron Oxide Nanoparticles on the Properties of Oil-Based Drilling Fluid." Journal of Energy Resources Technology 143, no. 4 (2020). http://dx.doi.org/10.1115/1.4048231.

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Abstract Lately, nanoparticles (NPs) have shown the potential to improve the performance of oil well fluids significantly. Several studies have reported the ability of NPs to produce improved properties of both water and oil-based drilling fluids. In this study, hydrophobic iron oxide NPs were synthesized by thermal decomposition of iron pentacarbonyl in an inert atmosphere, and its performance was tested in the oil-based drilling fluid with 90/10 oil-to-water ratio (base fluid). Oil-based drilling fluids treated with nanofluids were formulated by adding 0.5 wt% and 1.0 wt% iron oxide NPs in h

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28

Pratama, Raka Aditya, Astra Agus Pramana, and Bambang Kustono. "Aerated Drilling Optimization in Geothermal Well Drilling in Field “X” Cluster “Y”." Journal of Earth Energy Science, Engineering, and Technology 1, no. 2 (2018). http://dx.doi.org/10.25105/jeeset.v1i2.3945.

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<em>Aiming for productive fault in Suban Agung Rim, Field X Cluster Y Bengkulu Province, Indonesia, PT Pertamina Geothermal Energy (PGE) drilled some wells to discover the potential awaited. However there are challenge awaits each meter ahead especially in reservoir sections where loss circulation is expected. Knowing the risk, PGE decided to drill the well utilizing aerated drilling. The method has known for decades to be the most effective approach in dealing loss circulation. The method applies certain value of compressed air to be injected in fluid stream, so bubbling process can be

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29

Ismail, Issham, and Poon Huang Ann. "The Application Of Methyl Glucoside As Shale Inhibitor In Sodium Chloride Mud." Jurnal Teknologi, January 20, 2012. http://dx.doi.org/10.11113/jt.v50.175.

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Lumpur metil glukosida, atau dikenali sebagai MEG, ialah lumpur dasar air terkini yang mesra alam. Lumpur ini mempunyai prestasi yang hampir menyamai lumpur dasar minyak. Projek ini dilaksanakan bagi mengkaji kesan penambahan MEG ke dalam lumpur natrium klorida (MEG/NaCl) untuk mengawal pengembangan dan penyerakan syal pada beberapa kepekatan yang berlainan, iaitu 5% hingga 35% berdasarkan berat. Kajian ini melibatkan ujian penyerakan putaran panas yang berdasarkan American Petroleum Institute – Recommended Practice – 13I. Sifat pengawalan sedemikian turut dikaji menggunakan beberapa sampel sy

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