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1
Cai, Yong Peng, Guang Zheng Jia, Yong Liang Ren, and Shi Peng Chen. "Design of Hydraulic Experimental System of Oil Drilling and Production." Advanced Materials Research 986-987 (July 2014): 794–97. http://dx.doi.org/10.4028/www.scientific.net/amr.986-987.794.
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Designed a set of hydraulic experimental system for testing some performance parameters of oil drilling and production equipments and demonstrating its functions and principles. This system provided hydraulic environment for pumping unit, ESP (Electric Submersible Pump), well control devices, drilling and workover experiments, collected and analyzed experimental data, provided an important platform for the research and development of oil drilling and production equipments and experiment teaching. The functions and principles of hydraulic system’s components are introduced, and some main components are selected and designed in the system.
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Yaremiychuk, R. S. "DRILLING OF OIL AND GAS BORE: YESTERDAY, TODAY, TOMORROW." PRECARPATHIAN BULLETIN OF THE SHEVCHENKO SCIENTIFIC SOCIETY Number, no. 2(46) (December 14, 2018): 191–96. http://dx.doi.org/10.31471/2304-7399-2018-2(46)-191-196.
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The article deals with development of bore drilling technologies over the past 150 years. Rotor drilling and drilling with turbo booms, electric drills, screw engines are analyzed.According to the author drilling operations of bores should consist of two parts the first of which provides maximum possible drilling speed, and the second – the proper disclosure of productive strata.When implementing the first and second parts of the project it is recommended to use service system for the implementation of certain types of work with the involvement of specialists of the profile. This applies in the first place to the regulation of the properties of washing liquids, the modes of their circulation in the well, and also the processes of fixing the walls of the well. According to the author service companies should also be involved in all types of recovery of filtration characteristics of reservoir layers.
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Jonathan, Jonathan, Sisworini Sisworini, Samsol Samsol, and Hari Oetomo. "OPTIMASI PRODUKSI SUMUR EC-6 DENGAN MEMBANDINGKAN PENGANGKATAN BUATAN GAS LIFT DAN ELECTRIC SUBMERSIBLE PUMP." PETRO 8, no. 1 (April 20, 2019): 8. http://dx.doi.org/10.25105/petro.v8i1.4289.
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<em>In the world of oil is very common in the production system. This production system produces oil from wells after drilling and well compressions. Over time, the production of a well may decrease due to several parameters of pressure drop and the presence of clay which makes the pipe diameter narrower. There are several methods used to increase the decrease in production including adding artificial lifts such as sucker rod pump, electric submersible pump and gas lift, reservoir stimulation and pipe cleaning if the pipe diameter is reduced due to clay. The well has been installed an artificial lift is a gas lift and this well need an optimization to increase its production. The EC-6 well optimization is planned by comparing the lift-up scenario of the gas lift by adjusting the rate of gas injection and deepening the orifice injection and also an installation of electrical submersible pump. Best percentage of optimization production from EC-6 Well, last scenario is chosen which is new installation artificial lift ESP from gas lift (existing) and gaining 18.52% form existing production</em>
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Wang, Dong, Yongming Li, Haojie Yu, Ruizhi Tang, and Ningping Yan. "Optimization of the Oil Drilling Monitoring System Based on the Multisensor Image Fusion Algorithm." Journal of Sensors 2021 (September 6, 2021): 1–12. http://dx.doi.org/10.1155/2021/5229073.
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The working environment of the oil drilling platform is harsh, with many uncertain factors and high operating risks. During the drilling process, due to sudden formation factors or improper process operations, it is extremely easy to cause well wall instability, sticking, lost circulation, well kick, and blowout. In addition, other complicated situations and accidents have brought major challenges to drilling safety. In order to improve the technical level of oil and gas exploration and development and achieve the goal of reducing costs and increasing efficiency, it is necessary to strengthen the optimization of traditional oil drilling monitoring systems. This article summarizes the advantages and disadvantages of the existing image multiscale analysis algorithms, from wavelet transform, stationary wavelet transforms to contourlet transform, and nondownsampled contours based on the characteristics of the images collected by different sensors in the oil drilling monitoring system and the needs of practical applications. Wave transforms detailed comparison of the fusion performance of these image analysis algorithms under the same fusion rules. Aiming at the shortcoming of the large amount of calculation of nonsubsampled contourlet transform, a fast implementation algorithm (IFNSCT) is proposed. The multichannel filter bank structure is used to replace the original tree filter bank structure, which reduces the time-consuming to the original without affecting the analysis performance of the algorithm. One-half of the oil drilling monitoring efficiency has been improved.
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Lasserre, D. "FORMATION EVALUATION IN HIGHLY-DEVIATED, LONG REACH DEVELOPMENT WELLS ON THE NORTH RANKIN GAS FIELD, NW SHELF, AUSTRALIA." APPEA Journal 30, no. 1 (1990): 310. http://dx.doi.org/10.1071/aj89020.
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A large proportion of the North West Shelf development gas wells are long reach (greater than 3500 m) and highly deviated. For reservoir description and management purposes, comprehensive formation evaluation needs to be carried out in these wells.Considerable difficulties have been encountered with electric log data acquisition due to friction and borehole conditions in these long, highly-deviated wells. As a result, new techniques to log the zones of interest were introduced. A system using the drill pipe to transport the downhole logging tools has been successfully used.Also, low-toxicity oil-based mud (LTM) was introduced in order to ease drilling problems and borehole conditions. However, owing to the non-conductive nature of the oil-based drilling fluid, improvements were required in the vertical resolution of the resistivity measurements and the estimation of the formation porosity.A computer program using a forward deconvolution technique recently developed by Shell's research laboratory in Holland has been successfully applied to enhance the vertical resolution of the resistivity log reading.The large range of uncertainty on the pore volume has been reduced to reasonable level by calibrating the porosity log data against core data obtained in a well drilled with LTM.
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Bernardo, G., M. Marroccoli, M. Nobili, A. Telesca, and G. L. Valenti. "The use of oil well-derived drilling waste and electric arc furnace slag as alternative raw materials in clinker production." Resources, Conservation and Recycling 52, no. 1 (November 2007): 95–102. http://dx.doi.org/10.1016/j.resconrec.2007.02.004.
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Pogrebnaya, I. A., and S. V. Mikhailova. "Efficiency Analysis of the Geological-Technical Activities in Severo-Ostrovnoe Field." Journal of Computational and Theoretical Nanoscience 16, no. 11 (November 1, 2019): 4584–88. http://dx.doi.org/10.1166/jctn.2019.8359.
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The work is devoted to identifying the most relevant geological and technical measures carried out in Severo-Ostrovnoe field from the period of its development to the present. Every year dozens of geotechnical jobs (GJ) are carried out at each oil field-works carried out at wells to regulate the development of fields and maintain target levels of oil production. Today, there are two production facilities in the development of the Severo-Ostrovnoe field: UV1a1 and BV5. With the help of geotechnical jobs, oil-producing enterprises ensure the fulfillment of project indicators of field development (Mikhailov, N.N., 1992. Residual Oil Saturation of Reservoirs Under Development. Moscow, Nedra. p.270; Good, N.S., 1970. Study of the Physical Properties of Porous Media. Moscow, Nedra. p.208). In total, during the development of the Severo-Ostrovnoe field, 76 measures were taken to intensify oil production and enhance oil recovery. 12 horizontal wells were drilled (HW with multistage fracking (MSF)), 46 hydraulic fracturing operations were performed, 12 hydraulic fracturing operations were performed at the time of withdrawal from drilling (HW with MSF), five sidetracks were cut; eight physic-chemical BHT at production wells; five optimization of well operation modes. The paper analyzes the performed geological and technical measures at the facilities: UV1a1∦BV5 of the Severo-Ostrovnoe field. Four types of geological and technical measures were investigated: hydraulic fracturing, drilling of sidetracks with hydraulic fracturing, drilling of horizontal wells with multi-stage hydraulic fracturing, and physic-chemical optimization of the bottom-hole formation zone. It was revealed that two geotechnical jobs, namely, formation hydraulic fracturing (FHF) and drilling of lateral shafts in the Severo-Ostrovnoe field are the most highly effective methods for intensifying reservoir development and increasing oil recovery. SXL was conducted at 5 wells. The average oil production rate is 26.6 tons per day, which is the best indicator. Before this event, the production rate of the well was 2.1 tons per day. Currently, the effect of ongoing activities continues.
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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 (August 30, 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 as drilling depth increases, hence the stability of such fluids becomes an imperative parameter. Furthermore, emulsion itself is a heterogeneous fragile system so the stability was investigated using shear stress-shear rate rheology measurements. Emulsions have shown strong shear-thinning (pseudoplastic) behaviour which is considered an advantageous property for the drilling fluids. Experiments conducted to determine the dynamic rheology of the emulsions have shown the elastic behaviour towards emulsion breakdown processes. The fluids have also shown physical stability after 30 days at ambient conditions. Inter-facial variables such as zaeta potential, inter-racial tension (IFT) and contact angle measurements were conducted to examine their role in stability characterization.
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Mohamed, Abdelmjeed, Salem Basfar, Salaheldin Elkatatny, and Abdulaziz Al-Majed. "Prevention of Barite Sag in Oil-Based Drilling Fluids Using a Mixture of Barite and Ilmenite as Weighting Material." Sustainability 11, no. 20 (October 12, 2019): 5617. http://dx.doi.org/10.3390/su11205617.
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Drilling high-pressure high-temperature (HPHT) wells requires a special fluid formulation that is capable of controlling the high pressure and is stable under the high downhole temperature. Barite-weighted fluids are common for such purpose because of the good properties of barite, its low cost, and its availability. However, solids settlement is a major problem encountered with this type of fluids, especially at elevated downhole temperatures. This phenomenon is known as barite sag, and it is encountered in vertical and directional wells under static or dynamic conditions leading to serious well control issues. This study aims to evaluate the use of barite-ilmenite mixture as a weighting agent to prevent solids sag in oil-based muds at elevated temperatures. Sag test was conducted under static conditions (vertical and inclined) at 350 °F and under dynamic conditions at 120 °F to determine the optimum ilmenite concentration. Afterward, a complete evaluation of the drilling fluid was performed by monitoring density, electrical stability, rheological and viscoelastic properties, and filtration performance to study the impact of adding ilmenite on drilling fluid performance. The results of this study showed that adding ilmenite reduces sag tendency, and only 40 wt.% ilmenite (from the total weighting material) was adequate to eliminate barite sag under both static and dynamic conditions with a sag factor of around 0.51. Adding ilmenite enhanced the rheological and viscoelastic properties and the suspension of solid particles in the drilling fluid, which confirmed sag test results. Adding ilmenite slightly increased the density of the drilling fluid, with a slight decrease in the electrical stability within the acceptable range of field applications. Moreover, a minor improvement in the filtration performance of the drilling fluid and filter cake sealing properties was observed with the combined weighting agent. The findings of this study provide a practical solution to the barite sag issue in oil-based fluids using a combination of barite and ilmenite powder as a weighting agent to drill HPHT oil and gas wells safely and efficiently with such type of fluids.
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Bin Tajul Amar, Zarool Hassan. "The Benefits of Logging While Drilling (LWD) for Formation Evaluation in the Dulang West Field." SPE Reservoir Evaluation & Engineering 1, no. 06 (December 1, 1998): 496–503. http://dx.doi.org/10.2118/52567-pa.
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Summary Ever since the first electric log was run in 1927, the oil industry relied on wireline-conveyed logging for the acquisition of formation data for petrophysical analysis. It was not until 1978 that the first measurement while drilling (MWD) tools were introduced in the field. The industry did not pay too much attention to them then because they did not offer sufficient information for petrophysical analysis. Furthermore, the reliability of such tools was notimpressive and their cost was unattractive. However, over the last 6 years, the drilling services industry has shifted its focus from just directional MWD to a complete directional and logging while drilling (LWD) package. The LWD tools that are built into special drill collars provide measurements of resistivity, neutron, density, and gamma ray. Significant improvements in the reliability of the tools and competitive pricing, as compared to conventional wireline logging, has offered advantages in running LWD in fields that have drilling and completion constraints (e.g., borehole stability) or difficult well trajectories. This paper discusses the benefits to Petronas Carigali of using LWD for formation evaluation. In the development of the Dulang West field, LWD was used extensively to acquire formation log data. The quality of the data and cost savings are addressed. A comparison between the wireline-conveyed and LWD data acquired in this field is also presented. The acquisition of formation data by use of LWD in Dulang West has made a significant contribution to the overall cost per barrel of oil produced, without compromising data quality. P. 496
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Karpenko, Oleksiy, Vasyl Sobol, Mykyta Myrontsov, and Ivan Karpenko. "Detection of intervals / layers in sections of the wells with anomalous areas of drilling mud filtrate contamination according to the well logging (with negative test results of horizons)." E3S Web of Conferences 280 (2021): 09007. http://dx.doi.org/10.1051/e3sconf/202128009007.
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The zone of infiltration of the drilling fluid filtrate into the reservoir rock creates significant difficulties for the study by logging methods and during further testing of the formation. Due to the penetration of filtrate, significant contamination of the near-wellbore zone occurs. The porosity and filtration characteristics of reservoir rocks are changing. There is a possibility of blockage by filtrate in the invaded zone of oil or gas flow from the formation to the well. As a result of the studies carried out using well logging data, it was found that the presence and distribution of a mud cake on the borehole wall opposite the reservoir is an important factor influencing the process of filtration of the drilling fluid into the layers. On the examples of the Yablunivske oil and gas and Kolomatske gas fields of the Dnieper-Donets basin, it is shown that the absence of a mud cake on the borehole walls leads to the formation of maximum, anomalous zones of filtrate invasion. The determining of the diameter of the invaded zone was carried out according to the data of electrical logging methods. In addition, the diameter of the invaded zone was calculated as a solution direct task equation for the case of direct filtration without blocking by the mud cake. Comparison of the results of determining the diameter of the invaded zone by two methods made it possible to draw certain conclusions. An important conclusion is that even partial absence of mud cake on the reservoir wall in the well leads to horizontal and vertical filtration of the drilling fluid from the well into the formation. As a result, the invaded zone may be so deep, that the gas flow rate is absent even at high values of porosity, permeability and gas saturation
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Jiang, Runkun, Lei Mei, and Q. M. Zhang. "COMSOL Multiphysics Modeling of Architected Acoustic Transducers in Oil Drilling." MRS Advances 1, no. 24 (2016): 1755–60. http://dx.doi.org/10.1557/adv.2016.46.
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ABSTRACTIn the oil and gas industry, acoustic transducers have been found to provide valuable geological sonic information such as compressional wave velocity, shear wave velocity, and rock formation slowness. These data can be used to indicate lithology, determine porosity, detect over-pressured formation zones, and check well to well correlation. One category of such acoustic transducers is equipped with piezoelectric elements. Conventional piezoelectric transducers are packaged by epoxy resin. Because of the liquid nature of uncured epoxy resin, it is difficult to position the piezoelectric elements accurately. The introduction of polyether ether ketone (PEEK) as the packaging material solved this issue. Due to the ease of machining on solid form, architectures of the composite acoustic transducers can be devised with great flexibility and creativity. These designs can be modeled with finite element methods (FEM) and the best design for the oil drilling application can be finalized and fabricated.COMSOL Multiphysics® solves problems in a programming environment that integrates relevant physics. In this case, it includes electrical circuit, solid mechanics, acoustics, and piezoelectricity. Here a compete model and procedure to study the performance of an architected composite acoustic transducer is provided. The displacement analysis gives insights into the resonance modes of the piezoelectric elements. The acoustics analysis gives the necessary information on the acoustic performance of the transducers, such as acoustic pressure spatial distribution, acoustic pressure frequency response, transmitting voltage response, and directivity. These are important criteria to judge the effectiveness of an architected transducer.
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Wilt, Michael J., Evan Schankee Um, Edward Nichols, Chester J. Weiss, Gregory Nieuwenhuis, and Kris MacLennan. "Casing integrity mapping using top-casing electrodes and surface-based electromagnetic fields." GEOPHYSICS 85, no. 1 (January 1, 2020): E1—E13. http://dx.doi.org/10.1190/geo2018-0692.1.
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Wellbore integrity is of paramount importance to subsurface resource extraction, energy storage, and hazardous waste disposal. We have developed a simple noninvasive technology for casing integrity screening, based on the continuity of electrical current flow. Applying low-frequency current to a wellhead, with a distant return electrode, produces a casing current dependent on the background formation and the properties and depth extent of the well casing. These currents in turn generate surface electrical fields that can be captured in a radial profile and can be used to analyze properties of the well casing. Numerical modeling results reveal a strong relation of the electric field to the casing properties and depth extent of the well. A small breakage in the casing produces a profile coincident to a cased well with a completion depth above the break. A corroded patch, in which the casing conductivity is reduced, also alters the field profiles, and its depth may be estimated by comparing to the profile expected from the well completion diagrams. The electric field profiles are also strongly dependent on background resistivity distributions and on whether the well was drilled using water- or oil-based drilling fluids. We validate the proof of concept in a field experiment, in which we apply currents at the wellheads of two adjacent wells with different casing lengths in an area of known background resistivity. The two profiles are similar in appearance but are offset in amplitude by more than a factor of five, consistent with the theoretical analysis and the 3D modeling results. These results demonstrate that our approach has promise for mapping the general casing condition without well intervention. This approach can be a practical and effective tool for rapidly screening several wells before expensive logging-based technologies are used for casing inspection in detail.
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Radonjic, Mileva, and Arome Oyibo. "Comparative experimental evaluation of drilling fluid contamination on shear bond strength at wellbore cement interfaces." World Journal of Engineering 11, no. 6 (December 1, 2014): 597–604. http://dx.doi.org/10.1260/1708-5284.11.6.597.
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Wellbore cement has been used to provide well integrity through zonal isolation in oil and gas wells as well as geothermal wells. Failures of wellbore cement result from either or both: inadequate cleaning of the wellbore and inappropriate cement slurry design for a given field/operational application. Inadequate cementing can result in creation of fractures and microannuli, through which produced fluids can migrate to the surface, leading to environmental and economic issues such as sustained casing pressure, contamination of fresh water aquifers and, in some cases, well blowout. To achieve proper cementing, the drilling fluid should be completely displaced by the cement slurry, providing clean interfaces for effective bond. This is, however, hard to achieve in practice, which results in contaminated cement mixture and poor bonds at interfaces. This paper reports findings from the experimental investigation of the impact of drilling fluid contamination on the shear bond strength at the cement-formation and the cement-casing interfaces by testing different levels of contamination as well as contaminations of different nature (physical vs. chemical). Shear bond test and material characterization techniques were used to quantify the effect of drilling fluid contamination on the shear bond strength. The results show that drilling fluid contamination is detrimental to both cement-formation and cement-casing shear bond strength.
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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, methods of converting steam energy are used to create a torque of the drilling device with simultaneous steam treatment of the bottomhole zone of the reservoir. As well as the impact of an alternating electromagnetic field on the reservoir matrix and interstratal liquid fluids to create currents, increase the mobility of molecules of liquid fluids, and, as a consequence, increase the temperature and lower the viscosity of oil, which will increase oil recovery. As a result of numerous experimental experiments carried out using the original setup in the laboratory of the branch of the Tyumen Industrial University in Nizhnevartovsk, it was shown that a decrease in viscosity is observed only when exposed to simultaneous thermal and electromagnetic fields.
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Wu, Yongkang, Baoping Lu, Wei Zhang, Yandan Jiang, Baoliang Wang, and Zhiyao Huang. "A New Logging-While-Drilling Method for Resistivity Measurement in Oil-Based Mud." Sensors 20, no. 4 (February 16, 2020): 1075. http://dx.doi.org/10.3390/s20041075.
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Resistivity logging is an important technique for identifying and estimating reservoirs. Oil-based mud (OBM) can improve drilling efficiency and decrease operation risks, and has been widely used in the well logging field. However, the non-conductive OBM makes the traditional logging-while-drilling (LWD) method with low frequency ineffective. In this work, a new oil-based LWD method is proposed by combining the capacitively coupled contactless conductivity detection (C4D) technique and the inductive coupling principle. The C4D technique is to overcome the electrical insulation problem of the OBM and construct an effective alternating current (AC) measurement path. Based on the inductive coupling principle, an induced voltage can be formed to be the indirect excitation voltage of the AC measurement path. Based on the proposed method, a corresponding logging instrument is developed. Numerical simulation was carried out and results show that the logging instrument has good measurement accuracy, deep detection depth and high vertical resolution. Practical experiments were also carried out, including the resistance box experiment and the well logging experiment. The results of the resistance box experiment show that the logging instrument has good resistance measurement accuracy. Lastly, the results of the well logging experiment indicate that the logging instrument can accurately reflect the positions of different patterns on the wellbore of the experimental well. Both numerical simulation and practical experiments verify the feasibility and effectiveness of the new method.
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Pedrosa, Camilo, Arild Saasen, Bjørnar Lund, and Jan David Ytrehus. "Wet Drilled Cuttings Bed Rheology." Energies 14, no. 6 (March 16, 2021): 1644. http://dx.doi.org/10.3390/en14061644.
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The cuttings transport efficiency of various drilling fluids has been studied in several approaches. This is an important aspect, since hole cleaning is often a bottleneck in well construction. The studies so far have targeted the drilling fluid cuttings’ transport capability through experiments, simulations or field data. Observed differences in the efficiency due to changes in the drilling fluid properties and compositions have been reported but not always fully understood. In this study, the cuttings bed, wetted with a single drilling fluid, was evaluated. The experiments were performed with parallel plates in an Anton Paar Physica 301 rheometer. The results showed systematic differences in the internal friction behaviors between tests of beds with oil-based and beds with water-based fluids. The observations indicated that cutting beds wetted with a polymeric water-based fluid released clusters of particles when external forces overcame the bonding forces and the beds started to break up. Similarly, it was observed that an oil-based fluid wetted bed allowed particles to break free as single particles. These findings may explain the observed differences in previous cutting transport studies.
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Wright, Phillip M., Stanley H. Ward, Howard P. Ross, and Richard C. West. "State‐of‐the‐art geophysical exploration for geothermal resources." GEOPHYSICS 50, no. 12 (December 1985): 2666–96. http://dx.doi.org/10.1190/1.1441889.
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At the present stage of development, use of geothermal energy saves about 77 million barrels of oil per year worldwide that would otherwise be required for electrical power generation and direct heat applications. More than a dozen countries are involved in development of geothermal resources. Currently, only the moderate‐ and high‐temperature hydrothermal convective type of geothermal system can be economically used for generating electric power. Lower‐temperature resources of several types are being tapped for space heating and industrial processing. Geophysics plays important roles both in exploration for geothermal systems and in delineating, evaluating, and monitoring production from them. The thermal methods, which detect anomalous temperatures directly, and the electrical methods are probably the most useful and widely used in terms of siting drilling targets, but gravity, magnetics, seismic methods, and geophysical well logging all have important application. Advances in geophysical methods are needed to improve cost effectiveness and to enhance solutions of geologic problems. There is no wholly satisfactory electrical system from the standpoint of resolution of subsurface resistivity configuration at the required scale, depth of penetration, portability of equipment, and survey cost. The resolution of microseismic and microearthquake techniques needs improvement, and the reflection seismic technique needs substantial improvement to be cost effective in many hard‐rock environments. Well‐logging tools need to be developed and calibrated for use in corrosive wells at temperatures exceeding 200°C. Well‐log interpretation techniques need to be developed for the hard‐rock environment. Borehole geophysical techniques and geotomography are just beginning to be applied and show promise with future development.
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Karpenko, O., B. Sobol, M. Myrontsov, and I. Karpenko. "ANALYSIS OF THE INFLUENCE OF GEOLOGICAL FACTORS ON THE DEPTH OF THE FILTRATE INVADED ZONEAT THE PRIMARY DISCLOSURE OF GRANULAR RESERVOIRS ACCORDING TO THE WELL-LOGGING DATA." Visnyk of Taras Shevchenko National University of Kyiv. Geology, no. 4 (91) (2020): 16–21. http://dx.doi.org/10.17721/1728-2713.91.02.
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Possibilities of using the well-logging data for revealing the factors of the geological nature that influence the formation of invaded zone of a drilling mud filtrate at oil and gas wells drilling are considered. Electrical logging data were used with probes of different sizes and different types for adequate calculation of the relative diameter of the invaded zone. 5 wells from the gas condensate field were selected for analysis. The terrigenous section of the wells is represented by the alternation of argillites, siltstones and sandstones. Rocks reservoirs of granular type; the layers with thicknesses from 3,4 to 18,2 m were selected for analysis. The results of statistical analysis (cluster and factor analyzes) revealed 3 groups of rocks, the characteristic features of which are significantly differentfrom the invaded zone, layer thickness and porosity and gas saturation coefficients. It is established that for terrigenous sections with reservoir rocks of granular type (Serpukhovian) for one field on the example of 5 wells there is a maximum direct correlation between the value of the relative diameter of the invaded zone and the thickness of the layers. The conducted researches allow making prognostic estimations concerning the approximate distributions of diameters of an invaded zone in terrigenous cuts in case of accident-free drilling with observance of technological conditions.
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Stefatos, Aristofanis, Alexander Vereshagin, Jonny Hesthammer, Trond Kristian Kalstø, Susanne Sperrevik, and Adrian Robson. "CSEM-driven exploration over the Nordland Ridge." Interpretation 2, no. 3 (August 1, 2014): SH79—SH95. http://dx.doi.org/10.1190/int-2013-0160.1.
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Exploration efforts in the Nordland Ridge over the past two decades have resulted in the Norne, Urd, Alve, Falk, and Linerle discoveries. Besides these discoveries, several wells have failed expectations. Exploration efforts in this area are challenging because of the large variation in the rock properties of potential Triassic to early Jurassic traps that could be filled with viscous (heavy) oil. Application of controlled-source electromagnetic (CSEM) technology to derive the electrical resistivity distribution of the subsurface was thought by some oil companies to be the key that could unlock the exploration potential in the area. However, two dry wells in 2006 (6608/11-5 “Valkyrie”) and 2011 (6608/11-7s “Phoenix”) drew negative attention to CSEM within the exploration community because CSEM data were available in both cases prior to drilling. The wells targeted Jurassic Åre sands very close to the existing Linerle discovery with heavy oil in reservoir-quality Åre sandstones. The first well encountered less than 5 m of hydrocarbon traces in the Åre sands, while the second well was dry with a poorer-than-expected reservoir at target depth. This work examines the quality and reliability of the most recently acquired 3D CSEM survey. Previous interpretations are discussed in light of the 3D data and the latest drilling results. The CSEM-derived distribution of resistivity in the subsurface is in good agreement with all well log data proving that CSEM provides reliable information that can be used for interpretation and decision making. A strong and localized resistivity anomaly remains untested, although the last two wells drilled very close to it. Two interpretations were evaluated to explain the measured resistivity. The first inferred the presence of a localized sabkha evaporite in the late Carnian, while the second suggested the presence of a hydrocarbon-filled reservoir in erosional products near the base Cretaceous unconformity.
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Fedorova, L. V., S. K. Fedorov, Y. S. Ivanova, and V. N. Zaripov. "Improving the Durability of Drill Pipe Subs by Electromechanical Processing." Proceedings of Higher Educational Institutions. Маchine Building, no. 10 (727) (November 2020): 38–46. http://dx.doi.org/10.18698/0536-1044-2020-10-38-46.
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Increasing the durability of drill pipe subs is a pressing problem, a solution to which will improve the efficiency of oil and gas companies when drilling wells. Outer diameter wear, tears on the end surfaces of couplings and the end surfaces of pins, as well as blemishes on external and internal conical rotary-shouldered connections are the most typical defects of the subs. A study and comparative bench tests of the 5135 steel subs with the Z-117 screw were conducted. Testing of the subs with hardening of the work surface by electromechanical processing was done in comparison with the base technology (hardening and high tempering) and carbonitriding. The drill pipe subs were manufactured and hardened by OOO Alexandrovsky Drilling Equipment Plant on the 1М63 machine modernized for electromechanical processing. The comparative bench tests of the drill pipe subs were conducted by OOO Kovrovsky Drilling Equipment Plant on the coupling makeup machine MC-4 by screwing on / unscrewing threaded connections, taking into account the Russian Federation standards and recommendations of the American Petroleum Institute API 7. Electromechanical processing, being one of the method of hardening by a concentrated flow of electric energy of industrial frequency, builds up a gradient layer with the hardness of 52–56 HRC on the surface of the drill pipe subs. The results of the screwing on / unscrewing tests of threaded connections with a toot-joint thread demonstrated high efficiency of carbonitriding and electromechanical processing (500 and more cycles) as a method of increasing hardness of the work surfaces and low efficiency of the current bulk heat treatment (up to 47–66 cycles).
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Feder, Judy. "As Oil Transitions to “Energy,” OFS Firms Revisit Priorities and Positions." Journal of Petroleum Technology 73, no. 07 (July 1, 2021): 30–32. http://dx.doi.org/10.2118/0721-0030-jpt.
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As the oilfield service sector emerges from a downturn and into a post-COVID-19 world, the companies that comprise it are repositioning them-selves along with their product and service portfolios to demonstrate their ability to sustainably support both new energy solutions and legacy oil and gas customers. This will mean charting new paths through a rapidly changing energy sector and protecting core competencies while entering new markets full of both opportunity and uncertainty. That is already happening among the sector’s heavyweights. While they still have large legacy businesses focused on hydrocarbons, some are adopting broader energy services business models to reflect the move toward cleaner fuels and renewables. And some are diversifying into new industries altogether, where they can leverage their assets’ competencies to expand their revenue base and potentially broaden their appeal to investors. Capital Discipline and Patience Sriram Srinivasan, Halliburton’s company’s senior vice president, global technology, said his company is pursuing a long-term journey of looking for solutions to control emissions across the entire upstream operations spread. “It’s no longer just about deciding where or when to turn pumps on and off or change a gear in the engine powering the pumps in a hydraulic fracturing spread to get improved downhole outcomes. It’s also about embedding energy considerations for emissions reduction across the board,” he said. “We have always designed for performance, cost, serviceability, and operability. Now we’ve added emissions sustainability.” He used artificial lift as an example. “Electrical submersible pumps (ESPs) are big consumers of electricity. Anything you can do to improve the energy efficiency of ESPs goes a long way toward reducing carbon footprint.” Most ESPs today are powered by electric induction motors. Halliburton is now looking at permanent magnet motors and associated electronic drives to maximize the efficiency of the motors, and thus, the pumps. The pump design can also be made more efficient by optimizing the design of the impeller blades. “Another challenge,” he continued, “is that when sand gets into the pumps, it degrades efficiency, so the pump becomes less efficient the longer it stays in the well. We need changes in coatings to prevent sand from agglomerating on the blades. How do you get a cheap coating that will protect from sand?” Srinivasan also pointed out that energy efficiency can be improved and carbon footprint reduced by spending less time drilling the same kinds of wells, noting that standardization, digitalization, and automation are key enablers. “The industry is still heavily manual, many people are involved, and there is still way too much paper,” he said, adding that there is huge potential for efficiency improvements and also real urgency around achieving efficiency in every aspect of the drilling operation.
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Kessai, Idir, Samir Benammar, Mohamed Zinelabidine Doghmane, and Kong Fah Tee. "Drill Bit Deformations in Rotary Drilling Systems under Large-Amplitude Stick-Slip Vibrations." Applied Sciences 10, no. 18 (September 18, 2020): 6523. http://dx.doi.org/10.3390/app10186523.
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In oil and gas industry, rotary drilling systems are used for energy exploration and productions. These types of systems are composed of two main parts: mechanical and electrical parts. The electrical part is represented by rotating motor called top drive; however, the mechanical part of the system is composed of tool string with many pipes, at the bottom end of these pipes the bit is attached to cut the rock during their contact. Since the bit is in a direct contact with rock characteristic variations, it can be under risk for heavy damage. The latter is principally caused by the fact that the rock–bit interaction term is highly nonlinear and unpredictable. In literature, many mathematical models have been proposed for rock–bit interaction, but they do not reflect the dynamic of the bit under vibrations since torsional and axial vibrations are strongly coupled and synchronized with it. In industrial development, the design of drill bit has faced many improvements in order to overcome these vibrations and mitigate unpredictable phenomena. Even though, the practical use of these drill bits confirmed that there are still many failures and damages for the new designs; moreover, bits’ virtual life become shorter than before. The objective of this study is to analyze the drill bit deformations caused by the stick-slip vibration phenomenon which is characterized by high-frequency high-amplitude in rotary drilling systems. The obtained results were validated through a case study of MWD (measurement while drilling) data of well located in a Southern Algerian oil field.
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Knapik, Ewa, Katarzyna Chruszcz-Lipska, Łukasz Łukańko, and Sławomir Wysocki. "Reuse of Flowback Water from Hydraulic Fracturing for Drilling Mud Preparation and Secondary Hydrocarbon Recovery." Energies 14, no. 18 (September 17, 2021): 5921. http://dx.doi.org/10.3390/en14185921.
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Flowback water after completion of hydraulic fracturing is one of major waste streams generated during the lifespan of a well so its beneficial reuse is crucial. The application of treated flowback is not limited to stimulation processes but also may include drilling operations and secondary oil recovery. The flowback water used in this work is characterized by high salinity reaching up to ~295 g/L caused mainly by NaCl. The presence of suspended solids, mainly corrosion products, prompts the use of coagulation and filtration as treatment methods. Among tested coagulants the most effective one was the SAX18 (NaAlO2) commercial coagulant applied at concentration of 12 mL/L which reduces the water turbidity from over 400 FTU to 23 FTU. The applied treatment greatly reduces the concentration of scaling ions and so the concentration of SiO2 is reduced by 64%, Ba2+–66%, Fe2–36%, Mn2+–65%, SO42−–66%. The treated flowback fluid can be reused in surfactant flooding for enhanced oil recovery where achieves 7% higher displacing efficiency than fresh water. The drilling muds which were prepared using the untreated flowback water exhibit good rheological properties. The obtained results show that recycling of flowback water in future drilling and exploitation operations is technically feasible.
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Fu, Lipei, Kaili Liao, Bo Tang, Lujun Jiang, and Weiqiu Huang. "Applications of Graphene and Its Derivatives in the Upstream Oil and Gas Industry: A Systematic Review." Nanomaterials 10, no. 6 (May 26, 2020): 1013. http://dx.doi.org/10.3390/nano10061013.
Full textAbstract:
Graphene and its derivatives, with their unique two-dimensional structures and excellent physical and chemical properties, have been an international research hotspot both in the research community and industry. However, in application-oriented research in the oil and gas industry they have only drawn attention in the past several years. Their excellent optical, electrical, thermal and mechanical performance make them great candidates for use in oil and gas exploration, drilling, production, and transportation. Combined with the actual requirements for well working fluids, chemical enhanced oil recovery, heavy oil recovery, profile control and water shutoff, tracers, oily wastewater treatment, pipeline corrosion prevention treatment, and tools and apparatus, etc., this paper introduces the behavior in water and toxicity to organisms of graphene and its derivatives in detail, and comprehensively reviews the research progress of graphene materials in the upstream oil and gas industry. Based on this, suggestions were put forward for the future research. This work is useful to the in-depth mechanism research and application scope broadening research in the upstream oil and gas industry.
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Hasanov, A. S. "Tectonic state and oil-gas prospects of Khidirly-Bandovan structure according to the new gravimetric data." Azerbaijan Oil Industry, no. 6 (June 15, 2020): 11–18. http://dx.doi.org/10.37474/0365-8554/2020-6-7-11-18.
Full textAbstract:
Khidirly-Bandovan structures have been studied through geological mapping, structural exploration drilling, geophysical methods (gravimetric, magnetic, electrical, seismic exploration methods) since the 1930s. Small amount of oil from different wells in the upper part of Productive Series (PS) and huge amount of gas fountain from Middle Absheron sediments have been obtained. As the interest to these areas had not decreased, the geophysical surveys continued during further years. Seismic exploration surveys were executed in Bandovan structure via Common Depth Point (CDP) method in 2004, refracted ray method and gravimetric exploration complex in 2006 and 3D seismic exploration works and gravimetric investigations with “Scintrex CG-5 Autograv” devices in 2016, correspondingly. In the result of analysis of distribution characteristics for local gravimetric anomalies, as well as 3D descriptions of new gravimetric data, up-to-date logs on tectonic state of Khidirly-Bandovan structure have been obtained and as the new oil-gas exploration objects, the west and south-west wings of these structures highlighted.
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Barton, Colleen A., and Mark D. Zoback. "Discrimination of Natural Fractures From Drilling-Induced Wellbore Failures in Wellbore Image Data - Implications for Reservoir Permeability." SPE Reservoir Evaluation & Engineering 5, no. 03 (June 1, 2002): 249–54. http://dx.doi.org/10.2118/78599-pa.
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Summary Natural fractures and drilling-induced wellbore failures provide critical constraints on the state of in-situ stress and the direct applicability to problems of reservoir production, hydrocarbon migration, and wellbore stability. Acoustic, electrical, and optical wellbore images provide the means to detect and characterize natural fracture systems and to distinguish them from induced wellbore failures. We present new techniques and criteria to measure and characterize attributes of natural and induced fractures in borehole image data. These techniques are applied to the characterization of fracture permeability in two case studies. Introduction Wellbore image logs are extremely useful for identifying and studying a variety of modes of stress-induced wellbore failures. We present examples of how these wellbore failures appear in different types of image data and how they can be discriminated from natural fractures that intersect the wellbore. We then present brief overviews of two studies, which illustrate how the techniques have been applied to address specific issues of fracture permeability. Drilling-induced failures are ubiquitous in oil and gas and geothermal wells because the process of drilling a well causes a concentration of the far-field tectonic stress close to the wellbore, which often can exceed rock strength. Through the use of wellbore imaging and other logging techniques, stress-induced failures can be detected and categorized (compressive, tensile, or shear) and then used to estimate the unknown components of the stress field. We demonstrate how these modes of wellbore failures appear in different types of image data and the pitfalls in their interpretations. The most valuable use of drilling-induced features is to constrain the orientations and magnitudes of the current stress field. The use of drilling-induced features as stress indicators has become routine in the oil and gas industry.1–8 The detection of these features at the wellbore wall has become a primary target for Logging While Drilling/Measurement While Drilling (LWD/ MWD) real-time operations.9 A strong correlation between critically stressed fractures (fractures optimally oriented to the stress field for frictional failure) and hydraulic conductivity has been documented in a variety of reservoirs worldwide.10–12 When faults are critically stressed, permeabilities are increased, and the movement of fluid along faults is possible. We present examples of how knowledge of the stress state and natural fracture population may be used to access reservoir permeability. Drilling-Induced Tensile Wall Fractures Compressive and tensile failure of a wellbore is a direct result of the stress concentration around the wellbore, which results from drilling a well into an already stressed rock mass.13 Compressive wellbore failures (wellbore breakouts), first identified with caliper data, are useful for determining stress orientation in vertical wells.14–16 The study of such features with acoustic and electrical imaging devices makes it possible to clearly identify such features and to use them to determine stress magnitude and stress orientation.15,17–19 It is well known that if a wellbore is pressurized, a hydraulic fracture will form at the azimuth of the maximum horizontal stress.20 The formation of drilling-induced tensile wall fractures is the result of the natural stress state, perhaps aided by drilling-related perturbations, that causes the wellbore wall to fail in tension. The general case of tensile and compressive failure of arbitrarily inclined wellbores in different stress fields is described by Peska and Zoback,1 who demonstrate that there is a wide range of stress conditions under which drilling-induced tensile fractures occur in wellbores, even without a significant wellbore-fluid overpressure. We call these fractures tensile wall fractures because they occur only in the wellbore wall as a result of the stress concentration. These failures form in an orientation of the maximum principal horizontal stress in a vertical borehole (Fig. 1a) and as en echelon features in deviated wells (Fig. 1b). Because drilling-induced tensile wall fractures are very sensitive to the in-situ stress, they can be used to constrain the present state of stress.1,2,21–23 Pitfalls in Interpretation of Tensile Wall Fractures in Wellbore Image Data In cases in which drilling-induced tensile fractures form at an angle to the wellbore axis, it can be difficult to distinguish them from natural fractures, especially in electrical image logs that do not sample the entire wellbore circumference. Because misinterpretation of such features could lead to serious errors in the characterization of a fractured (or possibly not fractured!) reservoir, as well as the assessment of in-situ stress orientation and magnitude, we present criteria that are useful for discriminating natural from induced tensile fractures when observed in wellbore image logs. This is especially important because the wellbore stress concentration can have a significant effect on the appearance of natural fractures that intersect the wellbore. It is well known that fractures are mechanically weakened at their intersection with the borehole. This erosion causes the upper and lower peak and trough of the fracture sinusoid to be enlarged and subsequently enhanced in the standard 2D unwrapped view of wellbore image data (Fig. 2). Where the borehole hoop stress is tensile, the intersection of a natural fracture or foliation plane with the tensile region of the borehole may be preferentially opened in tension (Fig. 3a). These drilling-enhanced natural fractures can be mistaken easily for inclined tensile wellbore failures (Fig. 1b), thus resulting in serious errors in geomechanical modeling. Incipient wellbore breakouts are the early stages of wellbore breakout development, in which the borehole compressive stress concentration has exceeded the rock strength and initiated breakout development. The failed material within the breakout, however, has not yet spalled into the borehole (Fig. 3b). In a vertical borehole, these failures may appear as thin "fractures" that propagate vertically in the borehole and may be confused with drilling induced tensile wall cracks.
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Tewari, Saurabh, Umakant Dhar Dwivedi, and Susham Biswas. "A Novel Application of Ensemble Methods with Data Resampling Techniques for Drill Bit Selection in the Oil and Gas Industry." Energies 14, no. 2 (January 14, 2021): 432. http://dx.doi.org/10.3390/en14020432.
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Selection of the most suitable drill bit type is an important task for drillers when planning for new oil and gas wells. With the advancement of intelligent predictive models, the automated selection of drill bit type is possible using earlier drilled offset wells’ data. However, real-field well data samples naturally involve an unequal distribution of data points that results in the formation of a complex imbalance multi-class classification problem during drill bit selection. In this analysis, Ensemble methods, namely Adaboost and Random Forest, have been combined with the data re-sampling techniques to provide a new approach for handling the complex drill bit selection process. Additionally, four popular machine learning techniques namely, K-nearest neighbors, naïve Bayes, multilayer perceptron, and support vector machine, are also evaluated to understand the performance degrading effects of imbalanced drilling data obtained from Norwegian wells. The comparison of results shows that the random forest with bootstrap class weighting technique has given the most impressive performance for bit type selection with testing accuracy ranges from 92% to 99%, and G-mean (0.84–0.97) in critical to normal experimental scenarios. This study provides an approach to automate the drill bit selection process over any field, which will minimize human error, time, and drilling cost.
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Lozin, Evgeny V. "To the experience of Shkapovo oilfield development." Georesursy 21, no. 4 (October 30, 2019): 119–22. http://dx.doi.org/10.18599/grs.2019.4.119-122.
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The article formulates the main conclusions about the development of a large Shkapovsky oil field with an emphasis on the results of the development of the main objects – horizons DI and DIV of the terrigenous Devonian. The field was commissioned following the neighboring Tuimazinsky and Serafimovsky fields, taking into account the experience of a scientifically organized system for the development of these large platform oil fields in the Volga-Ural oil and gas region. It is shown that this experience was not taken into account much, especially in relation to the unsecured needs of oil production with capital construction, material and technical supply and social facilities. The potential of the field was realized in 18 years. Intra-contour and focal flooding, production technologies using electric centrifugal pumps (ESP), chemicalization of oil extraction processes, primary collection and transportation of products, oil, gas and water treatment technologies, etc., accelerated the development. Shkapov engineers and scientists own a number of innovations: realizing high development rates, means of preventing and eliminating salt-paraffin deposits, the introduction of double-barrel drilling, the development of high-performance ESPs, separate development of facilities, etc. At the same time, tasks were solved on eliminating ecological imbalance in the bowels and the environment, housing and public works. The current urgent problem of the field’s additional development is the activation of the production of residual oil reserves from oil and watered zones drilled with an unreasonably rare grid of wells. The final oil recovery coefficients of the Devonian objects are expected to be high, but, according to the author of the article, could reach CU 0.6.
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van Kessel, Onno. "Champion East: Low-Cost Redevelopment of Shallow, Stacked, and Faulted Heavy-Oil Reservoirs." SPE Reservoir Evaluation & Engineering 5, no. 04 (August 1, 2002): 295–301. http://dx.doi.org/10.2118/78674-pa.
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Summary The Champion East area offshore Brunei Darussalam consists of approximately 50 stacked, shallow, and intensely faulted heavy oil reservoirs. These reservoirs have been under development since 1975 and have to date produced just 9% of the oil initially in place. Over the period 1998-2003, Brunei Shell Petroleum (BSP) is embarking on a major redevelopment with the aim of converting a further 30 million m3 of oil-in-place volume into commercial reserves. An overview will be given of how new technology is adding value to the total redevelopment, supported by actual application results and learning points. The primary development of Champion East is now nearing completion. The use of existing facilities and ultra shallow, long reach horizontal wells - with innovative sand exclusion and downhole intelligence - has achieved a 60% unit cost reduction over previous drilling campaigns in the area. The only way to unlock another 5 to 15% of the oil-in-place volume is to start secondary recovery through water injection, in combination with the use of electric submersible pumps (ESPs). Introduction The Champion Asset comprises the Champion Field offshore Brunei Darussalam (Fig. 1) and all associated facilities and infrastructure, which also serve as an export hub for BSP's entire Offshore East production division. Oil production from the Champion Field averages approximately one-third of total BSP production. A large scope for recovery, mostly technology-driven, remains, even at low oil prices. Subsurface, the area comprises a hydrostatic, heterolithic sequence of interbedded thin sandstones and mudstones (with reservoir flow units no more than 15 m thick and permeabilities ranging from 0.01 to 0.2 µm2 in lower shoreface sands to 0.5 to 5 µm2 in tidal channels) deposited in environments spanning a systems tract that extends from the outer shelf into the lower coastal plain. Other key features are significant lateral thickness variations, compartmentalization caused by syndepositional tectonics, and the presence of multiple growth faults. The Champion field can be divided into two distinct parts (Fig. 2): Champion East, spanning a depth of approximately 200 to 1200 m, with hydrocarbons in some places seeping through the seabed and feeding a coral reef; and Champion Main, which encompasses a depth of approximately 1000 to 2000 m. Champion Main contains the mature core of the Champion field, where both primary and secondary (water-injection) recovery processes are well advanced and 28% of the oil initially in place has been produced. The main focus in Champion Main is on water-injection maintenance, production-system optimization, and scope for recompleting or sidetracking existing wells-all aimed at slowing the decline in oil production. Most efforts in the area are, however, focused on the growth potential offered by shallow reservoirs. The Champion East area is much less mature than Champion Main, with a cumulative oil production to date of just 9% of the oil initially in place. Historically, Champion East is underdeveloped because of its subsurface complexity and heterogeneity (leading to erratic well performance), less favorable reservoir and oil properties [density of 930 g/cm3 (20° API) and viscosity between 5 and 15 mPa's], and a perceived lack of spare conductor slots, which would necessitate large investments in new infrastructure. In 1995, it was estimated that an upfront investment in excess of U.S. $400 million would be required to advance the development of Champion East by accessing another 30 million m3 of undeveloped reserves. Out of this total, 40% would be required for new facilities, and the remaining 60% would be for drilling new wells. This hurdle essentially halted further developments (between 1992 and 1997, just one well was drilled in the area), and it was obvious that major changes were required to all the fundamentals (average reserves and rates per well, well costs, and facilities costs) to break this deadlock. The case for change, together with plans for possible solutions, is further described in Ref. 1. Reservoir Modeling Technology Traditionally, Champion East had been modeled with 2D methods of mapping gross interval properties for groups of reservoirs ranging in thickness from 20 to 40 m, using the previous 3D seismic survey shot in 1983 (relatively poor resolution) and well correlation methods based on lithostratigraphy. However, these methods often can prove unreliable in deltaic reservoirs that have undergone synsedimentary tectonics. The previous major Champion East infill drilling campaign (1990-92) was relatively unsuccessful because approximately 35% of all target reservoirs were found to be either nonexistent, water-bearing, or depleted. It then became clear that it was necessary to understand the structure, sequence stratigraphy, and fluid distribution of these reservoirs in greater detail. Two key data acquisition activities occurred in 1994: a high-resolution 3D seismic survey and the retrieval of some 350 m of continuous cores to review the sedimentology and high-resolution sequence stratigraphy, as described in Ref. 2. After screening studies to establish the correct priority and level of detail required, Shell's proprietary reservoir modeling software (GEOCAP-MoReS) was used to provide detailed 3D reservoir models for reservoir simulation. A total of 16 models were built and history matched (with approximately 50,000 grid cells each) between 1996 and 1999; together, they covered the entire area, with boundaries positioned (generally at sealing faults) to minimize crossflow effects. This allowed fast optimization of reservoir development plans by identifying connected oil in place and transmissibility for individual reservoir flow units, such as an upper shoreface sandbody or a tidal channel, which have remained undrained from previous development.
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Constable, Steven, and Leonard J. Srnka. "An introduction to marine controlled-source electromagnetic methods for hydrocarbon exploration." GEOPHYSICS 72, no. 2 (March 2007): WA3—WA12. http://dx.doi.org/10.1190/1.2432483.
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Early development of marine electromagnetic methods, dating back about 80 years, was driven largely by defense/military applications, and use for these purposes continues to this day. Deepwater, frequency-domain, electric dipole-dipole, controlled-source electromagnetic (CSEM) methods arose from academic studies of the oceanic lithosphere in the 1980s, and although the hydrocarbon exploration industry was aware of this work, the shallow-water environments being explored at that time were not ideally suited for its use. Low oil prices and increasingly successful results from 3D seismic methods further discouraged investment in costly alternative geophysical data streams. These circumstances changed in the late 1990s, when both Statoil and ExxonMobil began modeling studies and fieldtrials of CSEM surveying in deep water (around [Formula: see text] or deeper), specifically for characterizing the resistivity of previously identified drilling targets. Trials offshore Angola in 2000–2002 by both these companies showed that CSEM data can successfully be used to evaluate reservoir resistivity for targets as deep as several thousand meters. Both companies leveraged instrumentation and expertise from the academic community to make swift progress. The resulting rapid growth in the use of marine EM methods for exploration has created a demand for trained personnel that is difficult to meet; nevertheless, at this time, CSEM data represent a commercial commodity within the exploration business, and acquisition services are offered by three companies. The ability to determine the resistivity of deep drilling targets from the seafloor may well make marine CSEM the most important geophysical technique to emerge since 3D reflection seismology.
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Yan, Xiaolun, Jianye Mou, Chuanyi Tang, Huazhi Xin, Shicheng Zhang, Xinfang Ma, and Guifu Duan. "Numerical Investigation of Major Impact Factors Influencing Fracture-Driven Interactions in Tight Oil Reservoirs: A Case Study of Mahu Sug, Xinjiang, China." Energies 14, no. 16 (August 10, 2021): 4881. http://dx.doi.org/10.3390/en14164881.
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Fracture-driven interactions (FDIs) in unconventional reservoirs significantly affect well production and have thus garnered extensive attention from the scientific community. Furthermore, since the industry transitioned to using large completion designs with closer well spacing and infill drilling, FDIs have occurred more frequently and featured more prominently, which has primarily led to destructive interference. When infill wells (i.e., “child” wells) are fractured, older, adjacent producing wells (i.e., “parent” wells) are put directly at risk of premature changes in production behavior. Some wells may never fully recover following exposure to severe FDIs and, in the worst case scenario, will permanently stop producing. To date, previous investigations into FDIs have focused mainly on diagnosis and detection. As such, their formation mechanism is not well understood. To address this deficiency, a three-dimensional, multi-fracture propagation simulator was constructed based on the unconventional fracture model (UFM) and applied to a system that included both an older, adjacent passive well (“parent” well) and an active well (“child” well). Herein, the theoretical framework for overall complex fracture modeling is described. Furthermore, numerical simulation results are presented, demonstrating the critical roles of in-situ stress distribution and pre-existing natural fractures and aiding in the development of appropriate strategies for managing FDIs.
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Huang, Zhao Hui, Chang Chun Zou, and Zhen Ya Chen. "The Underground Water Quality Evaluation from Electrical Logging Data in Sandstone District: A Case Study in Daqing Oil Field." Applied Mechanics and Materials 256-259 (December 2012): 2424–30. http://dx.doi.org/10.4028/www.scientific.net/amm.256-259.2424.
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As an important yardstick of water quality evaluation, total dissolved solids (TDS) is strongly correlated with apparent resistivity and static spontaneous potential (SSP) parameters from electrical logging curves.A lot of electrical logging data accumated in the hydrogeologic survey during last decades can be used to predict the underground water TDS. Based on electrical characteristic analysis of sandstone reservoir, taking the influfential factors of the Archie’s Equation and creation mechanism of spontaneous potential (SP) as starting points, the theoretical relationship between the underground water TDS and formation resistivity (Rt) without considering the infuence of the porosity is modeled in this paper, and also the relationship between the underground water TDS and SSP in the same section of drilling well. Utilizing the apparent resistivity logging and static potential logging data, and employing the numerical fitting method, the relationship between groundwater TDS and conductivity is analyzed and determined, finally, the electrical parameters of determining the water quality and the regional evaluation of water quality are expounded in Daqing oil field,songliao plain Quaternary sandstone aquifer.
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Titov, Konstantin V., Alexander Levitski, Pavel K. Konosavski, Andrey V. Tarasov, Yuri T. Ilyin, and Michel A. Buès. "Combined application of surface geoelectrical methods for groundwater flow modeling: A case history." GEOPHYSICS 70, no. 5 (September 2005): H21—H31. http://dx.doi.org/10.1190/1.2076747.
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Electrical methods [electrical profiling and sounding, induced polarization (IP), and self-potential (SP)], combined with geochemical and hydrochemical surveys, were applied to characterize shallow sediments at a site contaminated by oil-related brines. The site is located within the Romashkinskoye oil field (Tatarstan Republic, Russian Federation). Results of geochemical and hydrochemical surveys, as well as those of electrical profiling, revealed no individual haloes of contaminant in the soil and groundwater, which suggests that the entire site is contaminated. Vertical electrical IP soundings (VES-IP) allowed us to obtain the stratigraphic characteristics of the site and to distinguish a shallow aquifer among clayey aquitards. Interpretation of SP data on the basis of forward numerical modeling helped us to develop a groundwater-flow model of the site. To reduce ambiguities, we kept fixed the values of layer resistivity derived from the inverted VES-IP data. Boundary conditions on water head and water flow were based on drilling and sampling data. We varied only the values of hydraulic conductivity to fit the calculated SP values to the measured SP values. We found a strong misfit between the measured and calculated SP values for the one-aquifer model. By inferring a second, deeper-seated aquifer, we computed a two-aquifer model that produced a satisfactory SP fit.
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Chmielowska, Anna, Anna Sowiżdżał, and Barbara Tomaszewska. "Prospects of Using Hydrocarbon Deposits from the Autochthonous Miocene Formation (Eastern Carpathian Foredeep, Poland) for Geothermal Purposes." Energies 14, no. 11 (May 26, 2021): 3102. http://dx.doi.org/10.3390/en14113102.
Full textAbstract:
There are many oil and gas fields around the world where the vast number of wells have been abandoned or suspended, mainly due to the depletion of reserves. Those abandoned oil and gas wells (AOGWs) are often located in areas with a prospective geothermal potential and might be retrofitted to a geothermal system without high-cost drilling. In Poland, there are thousands of wells, either operating, abandoned or negative, that might be used for different geothermal applications. Thus, the aim of this paper is not only to review geothermal and petroleum facts about the Eastern Carpathian Foredeep, but also to find out the areas, geological structures or just AOGWs, which are the most prospective in case of geothermal utilization. Due to the inseparability of geological settings with both oil and gas, as well as geothermal conditionings, firstly, the geological background of the analyzed region was performed, considering mainly the autochthonous Miocene formation. Then, geothermal and petroleum detailed characteristics were made. In the case of geothermal parameters, such as formation’s thickness, temperatures, water-bearing horizons, wells’ capacities, mineralization and others were extensively examined. Considering oil and gas settings, insights into reservoir rocks, hydrocarbon traps and migration paths issues were created. Then, for evaluating geothermal parameters for specific hydrocarbon reservoirs, their depths were established based on publicly available wells data. Thereafter, the average temperatures for selected reservoirs were set. As the effect, it turned out that most of the deposits have average temperatures of 40/50 °C, nonetheless, there are a few characterized by higher (even around 80 °C) temperatures at reasonable depths.
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Valdez, Benjamin, Michael Schorr, and Jose M. Bastidas. "The natural gas industry: equipment, materials, and corrosion." Corrosion Reviews 33, no. 3-4 (July 1, 2015): 175–85. http://dx.doi.org/10.1515/corrrev-2015-0012.
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AbstractCorrosion is a crucial worldwide problem that strongly affects the oil and gas industry. Natural gas (NG) is a source of energy used in industrial, residential, commercial, and electric applications. The abundance of NG in many countries augurs a profitable situation for the vast energy industry. NG is considered friendlier to the environment and has lesser greenhouse gas emissions compared with other fossil fuels. In the last years, shale gas is increasingly exploited in the USA and in Europe, using a hydraulic fracturing (fracking) technique for releasing gas from the bedrock by injection of saline water, acidic chemicals, and sand to the wells. Various critical sectors of the NG industry infrastructure suffer from several types of corrosion: steel casings of production wells and their drilling equipment, gas-conveying pipelines including pumps and valves, plants for regasification of liquefied NG, and municipal networks of NG distribution to the consumers. Practical technologies that minimize or prevent corrosion include selection of corrosion-resistant engineering materials, cathodic protection, use of corrosion inhibitors, and application of external and internal paints, coatings, and linings. Typical cases of corrosion management in the NG industry are presented based on the authors’ experience and knowledge.
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Nooripoor, Vahid, and Abdolnabi Hashemi. "Effect of a modified nano clay and nano graphene on rheology, stability of water-in-oil emulsion, and filtration control ability of oil-based drilling fluids: a comparative experimental approach." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 75 (2020): 40. http://dx.doi.org/10.2516/ogst/2020032.
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During the past decade, researchers have used different Nano-Particles (NPs) due to their unique characteristics for improving formulation of Oil-Based Drilling Fluids (OBDFs). This study is the first research that investigates the effect of a Modified Nano Clay (MNC), namely CLOISITE 5 and non-functionalized Nano Graphene (NG) on rheology, electrical/emulsion stability, and filtration control ability, as the main properties of OBDFs. Initially, five concentrations of both NPs (0.25, 0.5, 1, 1.5, and 2 wt%) were added separately into an NP-free OBDF (the base fluid). Then, rheological properties and electrical stability of all prepared fluids were measured at three 90, 140, and 180 °F temperatures. Moreover, filtration test was carried out under 500 psi (3447 kPa) differential pressure and exposed to 300 °F temperature for all fluids. Since experimentally measured shear stresses followed well both Herschel Bulkley (shear-thinning) and Bingham Plastic models, effects of temperature and the NPs concentration on both model parameters are investigated more deeply in the paper. Activation energies calculated from Arrhenius model showed that MNC is more effective than NG on reducing the dependency of apparent and plastic viscosities of the base fluid on temperature. MNC, due to its amphiphilic structure, significantly stabilizes water-in-oil emulsion at all temperatures and concentrations, but NG with high electrical conductivity reduces the emulsion stability. The nanofluids containing 0.5 wt% MNC and 0.25 wt% NG which have respectively 32.6% and 43.5% fewer filtrate volumes than the base fluid, were considered as the optimal nanofluids from controlling filtration into formation aspect. Finally, MNC is applicable to enhance the formulation of the OBDF through supporting its commercial viscosifier, emulsifiers, and fluid loss control agent, but the negative effect of NG on emulsion stability limits its application.
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Cai, Zhixiang, Hui Zhang, Kerou Liu, Yufei Chen, and Qing Yu. "Experimental Investigation and Mechanism Analysis on Rock Damage by High Voltage Spark Discharge in Water: Effect of Electrical Conductivity." Energies 13, no. 20 (October 18, 2020): 5432. http://dx.doi.org/10.3390/en13205432.
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High voltage spark discharge (HVSD) could generate strong pressure waves that can be combined with a rotary drill bit to improve the penetration rate in unconventional oil and gas drilling. However, there has been little investigation of the effect of electrical conductivity on rock damage and the fragmentation mechanism caused by HVSD. Therefore, we conducted experiments to destroy cement mortar, a rock-like material, in water with five conductivity levels, from 0.5 mS/cm to 20 mS/cm. We measured the discharge parameters, such as breakdown voltage, breakdown delay time, and electrical energy loss, and investigated the damage mechanism from stress waves propagation using X-ray computed tomography. Our study then analyzed the influence of conductivity on the surface damage of the sample by the pore size distribution and the cumulative pore area, as well as studied the dependence of internal damage on conductivity by through-transmission ultrasonic inspection technique. The results indicated that the increase in electrical conductivity decreased the breakdown voltage and breakdown delay time and increased the energy loss, which led to a reduction in the magnitude of the pressure wave and, ultimately, reduced the sample damage. It is worth mentioning that the relationship between the sample damage and electrical conductivity is non-linear, showing a two-stage pattern. The findings suggest that stress waves induced by the pressure waves play a significant role in sample damage where pores and two types of tensile cracks are the main failure features. Compressive stresses close horizontal cracks inside the sample and propagate vertical cracks, forming the tensile cracks-I. Tensile stresses generated at the sample–water interface due to the reflection of stress waves produce the tensile cracks-II. Our study is the first to investigate the relationship between rock damage and electrical conductivity, providing insights to guide the design of drilling tools based on HVSD.
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Li, Zhong, Lai Bin Zhang, Fan Luo, Bai Ling Zhang, and Shu Ying Tan. "Mechanical Property Analysis of Materials and Application of Buttress Thread Buckle Marine Conductor." Advanced Materials Research 233-235 (May 2011): 2043–46. http://dx.doi.org/10.4028/www.scientific.net/amr.233-235.2043.
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At present, offshore drilling operations often use buttress thread casing as surface casing. The design conception of buttress thread casing comes from the offshore drilling’s demands and this kind of casing is mainly used as surface casing. This paper has taken material mechanical experiment, numerical simulation analysis and field test, the research results show that the various parameters of buttress thread casing fully complies with the drilling design requirements and the offshore oilfield production demands. This product can reduce drilling cost effectively, improve working efficiency and safety, and realize manufacture domestically. Meanwhile, the development of this project will fill the blank of the ERW (Electrical Resistance Weld) casing in CNOOC (China National Offshore Oil Corporation), and have a broad prospect of application.
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Xu, Chicheng, Carlos Torres-Verdín, and Shuang Gao. "Interpretation of hydraulic rock types with resistivity logs in Tertiary deepwater turbidite reservoirs: Pore-scale modeling verified with field observations in the Gulf of Mexico, USA." Interpretation 1, no. 2 (November 1, 2013): T177—T185. http://dx.doi.org/10.1190/int-2013-0037.1.
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Well-log-based hydraulic rock typing is critical in deepwater reservoir description and modeling. Resistivity logs are often used for hydraulic rock typing due to their high sensitivity to rock textural attributes such as porosity and tortuosity. However, resistivity logs measured at different water saturation conditions need to be cautiously used for hydraulic rock typing because, by definition, the properties of hydraulic rock types (HRT) are independent of fluid saturation. We compare theoretical models of electrical and hydraulic conductivity of clastic rocks exhibiting different pore-size distributions and originating from different sedimentary grain sizes. When rocks exhibiting similar porosity ranges are fully saturated with high-salinity water, hydraulic conductivity is dominantly controlled by characteristic pore size while electrical conductivity is only marginally affected by the characteristic pore size. As a result, rock types with similar porosity but different characteristic pore sizes cannot be effectively differentiated with resistivity logs in a water-bearing zone. In a hydrocarbon-bearing zone at irreducible water saturation, capillary pressure gives rise to specific desaturation behaviors in different rock types during hydrocarbon migration, thereby causing differentiable resistivity log attributes that are suitable for classifying HRT. Core data and well logs acquired from a deep-drilling exploration well penetrating Tertiary turbidite oil reservoirs in the Gulf of Mexico, verify that inclusion of resistivity logs in the rock classification workflow can significantly improve the accuracy of hydraulic rock typing in zones at irreducible water saturation. Classification results exhibit a good agreement with those obtained from nuclear magnetic resonance logs, but have relatively lower vertical resolution. The detected and ranked HRT exhibit different grain-size distributions, which provide useful information for sedimentary facies analysis.
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Rahmani, Reza, Ray E. Ferrell, and John Rogers Smith. "Multiscale Imaging of Fixed-Cutter-Drill-Bit-Generated Shale Cuttings." SPE Reservoir Evaluation & Engineering 19, no. 02 (April 1, 2016): 196–204. http://dx.doi.org/10.2118/176028-pa.
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Summary Shales account for more than 75% of the formations drilled worldwide, and fixed-cutter bits are used to drill most of the footage. Cutter/rock interactions after the initial failure of rock are shown to be a major source of drilling inefficiency. Analytical and numerical modeling was implemented to understand these interactions and their controlling factors, but a comprehensive model does not exist. This is mainly because of the complex nature of the problem that depends on several factors that include rock characteristics, pressure-and-temperature environment, bit design, and drilling-fluid properties. Having such a large range of factors requires a cross-disciplinary approach to tackle the problem. This paper is focused on fabric analysis of the rock cuttings. Recent developments in fabric-analysis techniques allow the study of the size, shape, composition, and spatial arrangement of particles and matrix constituents in fine-grained rocks. This has led to an increased understanding of compaction phenomena, shear strength, porosity, permeability, fracturing, electrical propagation, and seismic properties of the rock. Despite this, the changes in rock fabric during interaction with the drill bit are not well-understood. This work takes advantage of those techniques by analyzing the shale cuttings at the macro-, micro-, and nanolevels to understand how shales break and deform under confining pressure to better understand drill-bit/rock interactions. Cuttings recovered from a well in Tuscaloosa, Louisiana, drilled with fixed-cutter bits were analyzed in multiple scales: macro, micro, and nano. Shallower and deeper sections were drilled with water-based mud and oil-based mud (OBM), respectively. Samples were gathered from seven depth intervals ranging from 13,500 to 21,320 ft. The microscale analysis was performed with a X-ray computed-tomography scanning technique, whereas nanoscale analysis was performed with a scanning electron microscope (SEM). Shale-cuttings fabric was characterized by images produced by energy-X-ray-descriptive spectroscopy (EDS) and backscattered-electron microscopy of ion-milled samples. Cuttings were generally formed in the shape of layered ribbons in which the mud-facing side is uneven and serrated whereas the cutter side is smooth and has a darkened clay film. The size of the ribbons and thickness of the layers were larger in areas drilled with OBM. Cuttings accumulation in the form of a ball attached to some of the ribbons from drilling in OBM provided evidence that cutter balling can occur during field drilling operations. SEM-EDS analysis of cuttings showed significant accumulation of barite, a component in the drilling fluid, on the external surface of the serrated sides of the ribbons. In addition, scattered barite zones were found inside the cuttings. X-ray diffraction analyses indicated a mixed mineral assemblage dominated by quartz and smectite with minor illite, kaolinite, chlorite, mixed-layered materials, and traces of calcite and pyrite. It was hypothesized that the absence or scattered appearance of barite in some zones of produced cuttings, particularly the cutter side of the ribbon and the cutter ball, may relate to higher deformation of cuttings at those zones. In addition, the mechanism of cutter balling was explained with an analogy with metal-cutting theories. This was supported by comparison between the geometry of shale cuttings from this field and copper cuttings from single-cutter experiments. Structural analysis of cuttings from actual field drilling reinforced the relevance of the observations made during laboratory experiments. It also provided unique insights, observations, and incentives for additional investigation of how cuttings are formed and what influences dysfunctions or inefficiencies. This is a significant step in understanding shale/cutter interactions that severely affect the bit penetration rate, especially under high confining pressure.
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Pant, Bharat B., Lucky Withanawasam, Mike Bohlinger, Mark Larson, and Bruce W. Ohme. "High-Temperature Anisotropic Magnetoresistive (AMR) Sensors." Journal of Microelectronics and Electronic Packaging 12, no. 4 (October 1, 2015): 205–11. http://dx.doi.org/10.4071/imaps.481.
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Magnetic field sensors are employed in downhole oil and gas well drilling applications for azimuth sensing, orientation/rotation sensing, and magnetic anomaly detection. As the wells get deeper there is demand from industry to increase the operating temperature from ~175°C to ~225°C and higher. We have extended the operating regimen of silicon-based anisotropic magnetoresistive sensors to higher temperatures to address this demand. The low-frequency minimum detectable field of these sensors monotonically increases with increasing temperature. At room temperature it is 2.2 μG/√Hz@1 Hz reaching a value of 26 μG/√Hz@1 Hz at 225°C. Signal and noise density both increase with increasing sensor bias voltage such that low-frequency signal-to-noise ratio does not vary in the bias voltage range of 2.5–10 V. We achieve excellent linearity of transfer function in the ±0.8 Gauss range in a closed-loop configuration. Deviation from linearity increases monotonically with increasing temperature but remains <0.002% of full scale or 29 μGauss at 225°C. Using low-noise electronics, closed loop operation of a typical sensor shows 1 – σ measurement variability of 21 μGauss at 220°C. By a combination of averaging and closed-loop operation, an input step from 0 to 75 μGauss is replicated at the output to within 0.1 μGauss at 225°C. Initial measurements suggest survivability of these sensors at 225°C to 2,000 h.
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Ren, Chunhua, Xiaoming Hu, Poyun Qin, Leilei Li, and Tong He. "Signal filtering for a small-diameter, dual-axis FOG inclinometer." Sensor Review 38, no. 3 (June 18, 2018): 353–59. http://dx.doi.org/10.1108/sr-07-2017-0136.
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PurposeMeasurement-while-drilling (MWD) system has been used to provide trajectory and inclination parameters of the oil and gas well. Fluxgate magnetometer is a traditional choice for one MWD system; however, it cannot obtain effective trajectory parameters in nonmagnetic environments. Fiber-optic-gyroscope (FOG) inclinometer system is a favorable substitute of fluxgate magnetometer, which can avoid the flaws associated with magnetic monitoring devices. However, there are some limitations and increasing surveying errors in this system under high impact conditions. This paper aims to overcome these imperfections of the FOG inclinometer system.Design/methodology/approachTo overcome the imperfections, filtering algorithms are used to improve the precision of the equipment. The authors compare the low-pass filtering algorithm with the wavelet de-noising algorithm applied to real experimental data. Quantitative comparison of the error between the true and processed signal revealed that the wavelet de-noising method outperformed the low-pass filtering method. To achieve optimal positioning effects, the wavelet de-noising algorithm is finally used to inhibit the interference caused by the impact.FindingsThe experimental results show that the method proposed can ensure the azimuth accuracy lower than ±2 degrees and the inclination accuracy lower than ± 0.15 degrees under the condition of interval impact. The method proposed can overcome the interference generated by the impact in the well, which makes the instrument suitable for the measurement of small-diameter casing well.Originality/valueAfter conducting the wavelet threshold filtering on the raw data of accelerometers, the noise generated by the impact is successfully suppressed, which is expected to meet the special requirement of the down-hole survey environment.
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Manheim, F. T., E. E. Peck, and C. M. Lane. "Determination of Interstitial Chloride in Shales and Consolidated Rocks by a Precision Leaching Technique." Society of Petroleum Engineers Journal 25, no. 05 (October 1, 1985): 704–10. http://dx.doi.org/10.2118/12724-pa.
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Abstract We have devised a technique for determining chloride in interstitial water of consolidated rocks. Samples of rocks ranging from 5 to 10 g are crushed and sieved under controlled conditions and then ground with distilled water to submicron size in a closed mechanical mill. After ultra-centrifugation, chloride content is determined by coulometric titration. The chloride concentrations and total pore-water concentrations, obtained earlier from the same pore-water concentrations, obtained earlier from the same samples by low-temperature vacuum desiccation, are used to arrive at the "original" pore-water chloride concentrations by a simple iteration procedure. Interstitial chlorinity results obtained from Cretaceous and Jurassic strata in the Gulf of Mexico coastal areas ranged from 20 to 100 g/kg Cl with reproducibility approaching +/- 1%. We have also applied the technique to igneous and metamorphic bedrocks as well as ocean basalts containing 1 % water or less. Chloride values ranging from 6.7 to 20 g/kg with a reproducibility of about 5% were obtained. Introduction This paper outlines a technique for precision analysis of interstitial chloride and water content (porosity) of shales and other consolidated rocks from deep-earth strata. Nearly all the literature on the composition of interstitial water (formation fluid) of deep-earth strata refers to fluids from reservoir rocks or permeable horizons. In many areas, shales or other nonreservoir rocks constitute the bulk of sedimentary sequences. These rocks contain interstitial fluids of generally unknown composition. The paucity of data is caused partly by the lack of access to fresh cores and partly by analytical difficulties in obtaining interstitial water from such materials. Until the late 1960's, much of the analytical literature dealing with pore fluids from deep sedimentary nonreservoir rocks was published in the Soviet Union and in references cited by those authors. Since then, interest in several hydrochemical phenomena relating to nonreservoir rocks has increased among phenomena relating to nonreservoir rocks has increased among scientists in the U.S. and other Western countries: interest in hydrocarbon resources in overpressured strata dominated by undercompacted shales that may have anomalous chloride content; need for knowledge of the proportion of bound water (electrolyte-poor) in porosity proportion of bound water (electrolyte-poor) in porosity during quantitative interpretation of electrical logs for oil and gas saturation in shaly sands; need for better understanding of nonreservoir rocks as sealing beds for deep waste disposal; and, finally, a desire to understand better the hydrochemical history of deeper sedimentary basins. However, only a relatively few field studies are available on the topics in question. Many of these are student theses or work based on them. The basic procedure underlying the studies of interstitial water composition of shales is simply crushing and grinding a rock sample, leaching it with distilled water, and analyzing the leachate. The salt content of the solid is then related to an independent determination of total pore fluid or porosity. Techniques based on this principle were used for shallow groundwater studies, for general rocks, and for studying oilfield drill cores. Comments in the literature and our own experiments suggest that simple approaches to the leaching process may yield accuracies of 10 to 20% for chlorides in rocks with a significant PV fraction. As water contents decrease to 1%, however, an uncontrolled system may easily yield errors of several hundred percent and uncertainties associated with the bound water (see the section called Discussion). Most of the studies of interstitial chlorinity of water composition in deep oilfield strata have been performed on stored, dried, or partly dried materials and/or have used insufficiently documented or quantified techniques. The goal of this study has been to approach a reproducibility and relative accuracy of I % in the values of interstitial chloride, given our definition of mobile water discussed later. Sampling and Handling of Drilling-Core Samples A potential source of error in interstitial fluid analysis is the contamination of cores by drilling fluid. However, experience in the Deep Sea Drilling Project and other drilling studies 11–15 show that, if external contaminated layers are cut or chipped away from undeformed normal, non-fractured silty-clay cores soon after recovery, virtually unaffected inner sections can be obtained. Even permeable (reservoir-type) rocks sometimes may be sampled successfully for pore-fluid study. During wireline coring by the AMCOR project with the drilling vessel Glomar Conception on the Atlantic Continental Shelf, virtually identical pore-fluid chloride profiles were obtained in repeated drillings performed with seawater and freshwater drilling fluids (Fig. 1). SPEJ P. 704
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Błaż, Sławomir, Grzegorz Zima, Bartłomiej Jasiński, and Marcin Kremieniewski. "Invert Drilling Fluids with High Internal Phase Content." Energies 14, no. 15 (July 27, 2021): 4532. http://dx.doi.org/10.3390/en14154532.
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One of the most important tasks when drilling a borehole is to select the appropriate type of drilling fluid and adjust its properties to the borehole’s conditions. This ensures the safe and effective exploitation of the borehole. Many types of drilling fluids are used to drill holes for crude oil and natural gas. Most often, mainly due to cost and environmental constraints, water-based muds are used. On the other hand, invert drilling fluids are used for drilling holes in difficult geological conditions. The ratio of the oil phase to the water phase in invert drilling fluids the most common ratio being from 70/30 to 90/10. One of the disadvantages of invert drilling fluids is their cost (due to the oil content) and environmental problems related to waste and the management of oily cuttings. This article presents tests of invert drilling fluids with Oil-Water Ratio (OWR) 50/50 to 20/80 which can be used for drilling HPHT wells. The invert drilling fluids properties were examined and their resistance to temperature and pressure was assessed. Their effect on the permeability of reservoir rocks was also determined. The developed invert drilling fluids are characterized by high electrical stability ES above 300 V, and stable rheological parameters and low filtration. Due to the reduced content of the oil, the developed drilling fluid system is more economical and has limited toxicity.
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Akhundov, J. S. "Efficiency of releasing stuck drilling string." Azerbaijan Oil Industry, no. 4 (April 15, 2021): 14–16. http://dx.doi.org/10.37474/0365-8554/2021-4-14-16.
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While drilling oil and gas wells, 10–15 % of open part of wellbore consists of permeable fractured reservoirs and horizons. Despite of it, 70–80 % of failures occurring in wellbore fall on the permeable suites. After sticking electrical measurement only upper interval is specified. Then an oil patch is practically installed in abnormally complicated reservoirs in the upper permeable stuck and bottomhole intervals to prevent the complications and blowout. The drilling string often remains stuck beneath the upper suite in three-four suites to the bottomhole. It is necessary to install stepped oil bath to prevent it.
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Gurav, Abhijit, John Bultitude, John McConnell, and Reggie Phillips. "Robust Reliability of Ceramic Capacitors for Power Electronics." Additional Conferences (Device Packaging, HiTEC, HiTEN, and CICMT) 2018, HiTEC (May 1, 2018): 000138–42. http://dx.doi.org/10.4071/2380-4491-2018-hiten-000138.
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Abstract For applications using Wide Band Gap (WBG) semiconductors, and for electronics for down-hole drilling, oil exploration, geothermal energy generation and power electronics, there is a growing need for capacitors that have robust reliability at temperatures of 125°C, 150°C or above. The development of more energy efficient power converters and inverters based on WBG semiconductors is driving the adoption of higher temperatures in a growing number of power electronics and automotive circuits since these operate at higher junction temperatures than traditional silicon. This has led to a growing need for high temperature capacitors with robust reliability. A Class-I C0G dielectric has been developed using Nickel electrodes for high temperature application up to 200°C and beyond. Since it is a paraelectric linear dielectric, these capacitors exhibit highly stable capacitance as a function of temperature and voltage, possess low loss (DF) and can conduct high RMS currents with a low temperature rise compared to other capacitor solutions. To maximize the capacitance density and achieve a high degree of mechanical robustness, stacks and leaded form factors are commonly needed. Materials for assembly of stacks are of interest due to the challenge of higher cost of attachment materials based on gold-solders or nano-silver pastes, as well as due to the presence of lead (Pb) in common high melting point (HMP) solders. This paper will report electrical properties and reliability test data on these Class-I C0G ceramic capacitors and stacks at high temperatures. It will also review thermal robustness and electrical characteristics of stacks assembled using Pb-free transient liquid phase sintering (TLPS) materials based on Sn-Cu and In-Ag.
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Della Nave, Esteban, and Eduardo Natalio Dvorkin. "On the modeling of oil well drilling processes." Engineering Computations 32, no. 2 (April 20, 2015): 387–405. http://dx.doi.org/10.1108/ec-03-2013-0093.
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Purpose – The purpose of this paper is to present the development of a simulator of oil well drilling processes. Design/methodology/approach – The simulator incorporates the main variables that are used by drilling engineers in the definition of the drilling processes. The code is useful a priori, in the design of a drilling process, as a tool for comparing different design options and predicting their results and a posteriori of a failure to understand its genesis and therefore provide know-why to improve the drilling techniques. Findings – The developed finite element simulator uses a co-rotational Bernoulli beam element, an explicit time integration scheme and an explicit contact algorithm. The numerical results show that the simulator is stable and provides consistent solutions. Practical implications – During the drilling of oil wells, the fatigue damage and wear of the drilling column is of utmost concern. To determine the mechanical behavior of the drilling column standard simplified analyses are usually performed using commercially available codes; however, those standard analyses do not include a transient dynamic simulation of the process; hence, it is necessary to develop a specific tool for the detailed dynamic simulation of drilling processes. Originality/value – A simulator able to perform a description of the drilling process in the time range will be an important contribution to the tools used by drilling engineers.
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Dotsenko, V. A. "Assembly of PND oil-well drilling equipment." Chemical and Petroleum Engineering 32, no. 6 (November 1996): 559–62. http://dx.doi.org/10.1007/bf02416677.
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Salimi, Payam, Asghar Teymoorian Motlagh, and Kamran Rahimi Bisetooni. "Exploration of Bitumen (Natural Asphalt) using a combination of apparent Resistivity method and exploration drilling in Saleh-Abad area, Ilam Province Iran." JOURNAL OF ADVANCES IN NATURAL SCIENCES 1, no. 1 (August 12, 2014): 16–21. http://dx.doi.org/10.24297/jns.v1i1.381.
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Bitumen is a hydrocarbon material that accumulates near the earth's surface in the form of asphalt springs or in other forms under the act of hydrostatic pressures of oil reservoirs, it will form bitumen mines after undergoing polymerization process. This mineral (organic) matter is in close relationship to oil reservoirs present in the area, i.e. when oil moves or migrates from one place to another place some part of it will be separated and will remain in the form of streaks, lenses and etc. In this work, the exploration of bitumen resources in Saleh-Abad area, Ilam is carried out using geoelectrical data that were gathered in two-dimensional form, exploration drilling data and also geological data. Today the best method for underground studies and mineral explorations is geophysical studies and drilling exploration wells meanwhile. One of the best data acquisition methods in the Geoelectricity is two-dimensional data acquisition or in other words electrical imaging in two dimensions. Tomography or electrical apparent resistivity tomography is a geophysical technique that investigates underground structures in two or three dimensions. The advantage of ERT method in comparison with other traditional and routine methods is that it investigates the changes of electrical apparent resistivity either laterally (constant spacing traversing or CST) or vertically (vertical electrical sounding, VES) in space. Geophysical data acquisition of the mentioned mine was done using dipole-dipole array in two profiles upon which some points were proposed for exploration drilling. Exploration drilling was done in powder method on the geophysical profiles in six 15-meter bores which proved the high precision of apparent resistivity method for bitumen exploration. Interpretation and modeling of two profiles was carried out using RES2DINV and modeling of drilling Logs was done using LOGPLOT that both had a good conformity with geological data and surface outcrops.