Journal articles on the topic 'Oil wells – Hydraulic fracturing'
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1
Jasechko, Scott, and Debra Perrone. "Hydraulic fracturing near domestic groundwater wells." Proceedings of the National Academy of Sciences 114, no. 50 (November 27, 2017): 13138–43. http://dx.doi.org/10.1073/pnas.1701682114.
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Hydraulic fracturing operations are generating considerable discussion about their potential to contaminate aquifers tapped by domestic groundwater wells. Groundwater wells located closer to hydraulically fractured wells are more likely to be exposed to contaminants derived from on-site spills and well-bore failures, should they occur. Nevertheless, the proximity of hydraulic fracturing operations to domestic groundwater wells is unknown. Here, we analyze the distance between domestic groundwater wells (public and self-supply) constructed between 2000 and 2014 and hydraulically fractured wells stimulated in 2014 in 14 states. We show that 37% of all recorded hydraulically fractured wells stimulated during 2014 exist within 2 km of at least one recently constructed (2000–2014) domestic groundwater well. Furthermore, we identify 11 counties where most (>50%) recorded domestic groundwater wells exist within 2 km of one or more hydraulically fractured wells stimulated during 2014. Our findings suggest that understanding how frequently hydraulic fracturing operations impact groundwater quality is of widespread importance to drinking water safety in many areas where hydraulic fracturing is common. We also identify 236 counties where most recorded domestic groundwater wells exist within 2 km of one or more recorded oil and gas wells producing during 2014. Our analysis identifies hotspots where both conventional and unconventional oil and gas wells frequently exist near recorded domestic groundwater wells that may be targeted for further water-quality monitoring.
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Panikarovskii, V. V., and E. V. Panikarovskii. "METHODS OF INCREASING PROJECT LEVELS OF CRUDE OIL PRODUCTION AT THE DEVELOPMENT OF MULTILAYER DEPOSITS." Oil and Gas Studies, no. 6 (December 1, 2017): 95–101. http://dx.doi.org/10.31660/0445-0108-2017-6-95-101.
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A brief review of the work on intensifying the inflow and increasing the oil recovery of the Neocomian deposits of the Priobskoye field is expounded. The analysis of technologies for increasing oil recovery of AS10, AS11, AS12 is performed. The technology of hydraulic fracturing in production and injection wells and methods of selecting wells for hydraulic fracturing in the operational well stock of the Priobskoye field are considered. Based on the analysis of enhanced oil recovery technologies, the need for hydraulic fracturing in low-productivity reservoirs has been proved.
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Abass, S. Y. "STUDY OF FILTRATION OF FORMATION FLUIDSAFTER HYDRAULIC FRACTURING." Oil and Gas Studies, no. 4 (September 1, 2017): 50–54. http://dx.doi.org/10.31660/0445-0108-2017-4-50-54.
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The technology of conducting hydraulic fracturing in extracting and injection wells and the techniques of selection of wells for hydraulic fracturing in operational fund of wells of Priobskoye field had been reviewed. Based on the conducted analysis of technologies of enhanced oil recovery the necessity of conducting hydraulic fracturing in low-productivity reservoirs was proved.
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Shkryaba, I. T., S. F. Mulyavin, I. I. Kleshchenko, and V. Yu Kusakin. "ANALYSIS OF EFFICENCY OF MULTI-STAGE HYDRAULIC FRACTURING IN HORIZONTAL WELLS AT VYNGAPUROVSKOYE GAS FIELD." Oil and Gas Studies, no. 4 (September 1, 2017): 89–92. http://dx.doi.org/10.31660/0445-0108-2017-4-89-92.
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The analysis of efficiency at engaging into development of hard-to-recover reserves of oil of horizontal wells using multistage hydraulic fracturing has been conducted. The results are presented as a comparison of the dynamics of their work to directional wells, in which also hydraulic fracturing had been held.
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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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Bratov, Vladimir. "Numerical Models for Hydraulic Refracturing on Vertical Oil Wells." International Journal of Engineering & Technology 7, no. 4.26 (November 30, 2018): 279. http://dx.doi.org/10.14419/ijet.v7i4.26.27937.
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The paper presents an approach for simulation of refracturing treatment on vertical oil wells. The model is accounting for filtration of hydraulic fracturing fluid through the proppant packed inside the crack formed during previous hydraulic fracturing treatments. The simulations provide a possibility to estimate history of stress intensity factor appearing at the tip of the existing crack once the time profile of pressure within the wellbore is given. Introducing critical value of the stress intensity factor for the fractured media, time-to-fracture initiation (after pressure increase start) can be estimated and compared to instance of fracture event registered in real conditions. Also, the possibility of fracture reorientation through formation of new fractures at the region adjacent to the wellbore is studied.
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Cai, Bo, Yun Hong Ding, Hua Shen, Zhou Qi Cui, and Chun Ming He. "Hydraulic Fracturing Technology in Oil and Gas Development." Advanced Materials Research 962-965 (June 2014): 560–63. http://dx.doi.org/10.4028/www.scientific.net/amr.962-965.560.
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Fracturing as a method to stimulate shallow, hard rock oil wells dates back to the 1860s. The first hydraulic fracturing technology was applied in the US states of Pennsylvania, New York, Kentucky in 1947. Hydraulic fracture was formed by pumping the fracturing fluid into the wellbore at a sufficient rate to increase downhole pressure to exceed that of the pressure gradient of the rock. In this paper, a few key techniques including hydraulic fracturing for the development of oil and gas resources were introduced. It has become a common technique to enhance the production of low-permeability formations, especially unconventional reservoirs such as tight sands, coal beds, and deep shales. Therefore hydraulic fracturing has been considered as “killer mace” for development of unconventional hydrocarbon resources in the world.
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Cai, Bo, Yun Hong Ding, Yuan Peng Shi, and Yong Jun Lu. "Low-Damage Hydraulic Fracturing Design Technique to Exploration Wells of Erlian Basin in China." Advanced Materials Research 753-755 (August 2013): 48–52. http://dx.doi.org/10.4028/www.scientific.net/amr.753-755.48.
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In China,more and more low permeability reservoirs have become the mainly oil production potential part for the soaring consumer market. Hydraulic fracturing treatment has always been playing an important role in these low permeability reservoirs.however,some inappropricate fracturing designs and treatments may decrease the productions as a result of high damage within both formations and artifical fractures.In order to minimize reduce formation and fracture damage, we take the wells in Erlian Basin as an example to explain the low-damage hydraulic fracturing technique which had been used in many of oil fields .Through eight years step by step study and field application, a comprehensive industrialize design technology was put forward. By the application of this technique, the low-damage degree is highlighted compared to the past.As a result the performance of post-fracturing wells have remarkably improved.
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Yarkeeva, N. R., and A. M. Khaziev. "APPLICATION OF HYDRAULIC FRACTURING FOR INTENSIFYING OIL FLOW IN WELLS." Petroleum Engineering 16, no. 5 (December 2018): 30. http://dx.doi.org/10.17122/ngdelo-2018-5-30-36.
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Ponomareva, Inna N., and Dmitry A. Martyushev. "Evaluation of hydraulic fracturing results based on the analysis of geological field data." Georesursy 22, no. 2 (June 30, 2020): 8–14. http://dx.doi.org/10.18599/grs.2020.2.8-14.
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The relevance of the research is specified by the significant contribution of the oil produced as a result of hydraulic fracturing in the wells in its total production. A correct assessment of the results of actually carried out hydraulic fracturing will allow to develop clear recommendations on the further application of this method of oil production enhancement for the geological and physical conditions of specific fields. It was established that hydraulic fracturing in the well 221 of the Shershnevsky field (the Perm Territory, Russia) led to a change in interaction between wells within the entire element of the development system; it began to work as a single coordinated system. As a result of hydraulic fracturing, there was not just a redistribution of fluid drainage volumes. A synergistic effect arose when fracturing in one well led to an increase in fluid flow rates and coordinated operation of the entire element of the development system. It is likely that hydraulic fracturing in the well 221 led to a significant change in the geological and technological characteristics of the Bobrikovskian deposit of the Shershnevsky field to a greater extent than the volume of the drainage zone of this well. A whole system of channels with reduced filtration resistances appeared instead of a single crack, as is common in the classic representation of hydraulic fracturing. It should be noted that the approach presented in the article is the first very important step in a comprehensive analysis of the effective reservoir development based on the results of field monitoring. In the future, it is necessary to attract more detailed information about the interaction of wells. Only such a multilevel analysis will allow to substantiate the general conclusion about the hydraulic fracturing on the development of a reservoir and to confirm conclusively the effect of wells on each other, which can be individual in different parts of the reservoir.
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Li-yong, Yang, Yin Shun-li, Zhuang Tian-lin, Gou Xiao-ting, and Du Yu-qiao. "Research and Application of Hydraulic Injection Precise Fracturing Technology in W27 Oilfield." E3S Web of Conferences 252 (2021): 01059. http://dx.doi.org/10.1051/e3sconf/202125201059.
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W27 oilfield is a multi-layer heterogeneous low permeability reservoir, which has entered the middle and late stage of development. The main reservoir is flooded seriously, and the remaining oil distribution is complex. If conventional fracturing technology is adopted, the risk of longitudinal fracture communication with water layer or water-flooded layer is high, which is easy to cause high water cut after fracturing and affect the fracturing effect. According to the characteristics of fractured well reservoir, the hydraulic injection fracturing technology is optimized to optimize the position of injection point and fracturing process parameters, avoid pressing water layer, and achieve accurate reconstruction of potential reservoir. The technology was applied to 4 Wells on site, and the average daily oil gain per well was 6 tons and the average accumulated oil gain per well was 2,500 tons. Hydraulic injection precision fracturing technology has an obvious effect on water control and oil increase in W27 oilfield, which has an important guiding significance for similar reservoirs to improve the fracturing effect.
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English, Rebecca. "Shake, Rattle, and Oil." Texas A&M Journal of Property Law 2, no. 3 (April 2015): 387–411. http://dx.doi.org/10.37419/jpl.v2.i3.2.
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This Article will delve into the possibility of wastewater injection wells as being the ultimate cause of the increased seismic activity in the United States. First it will outline the background of hydraulic fracturing and the water usage involved in the fracturing process. Next it will discuss the wastewater fluids as a by-product of the fracturing process and the resulting need for wastewater injection wells. Next this Article will outline the regulation of these fluids through the federal government and the state governments, with an emphasis on Texas and Ohio regulations. Lastly, this Article will outline two recommendations which will attempt to curtail the injection well-induced seismic activity problem: first by implementing quantitative field level permitting requirements, and second by expanding the implementation of water recycling techniques in the oil and gas industry.
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Wang, Jun Qi, and Ni Li. "Controlling Fracture Height in Fracturing Effect Prediction of Oil Well Based on Uncertain Multi-Attribute Decision Making." Advanced Materials Research 457-458 (January 2012): 989–93. http://dx.doi.org/10.4028/www.scientific.net/amr.457-458.989.
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Hydraulic fracture to oil well, creating fracture in the bottom stratum, making the crude oil flow to the bottom along the fracture are common stimulation treatment used in oil field. Controlling fracture height fracturing is controlling the extension of fracture within oil layer area, which is the key to success or failure of hydraulic fracturing. Especially, controlling fracture height to avoid pressing to wear the near water layer, which causes a sudden increase of oil water production, is particularly important to oil production. Fracture extension theory and field practice indicate that in controlling fracture height fracturing process, the fracture height extension is related with reservoir stress difference of oil layer and adjacent barrier on a certain scale of construction also it is related with the 8 parameters such as the rock Young's modulus, fracture toughness, Poisson's ratio, permeability, reservoir thickness, fracturing fluid viscosity and fluid loss coefficient and so on. This study introduces uncertain multi-attribute decision making method to the well needing controlling fracture height fracturing, takes expected minimum fracture height as the target, concentrates the 8 attribute values of oil well with OWA operator, obtains comprehensive attribute value, and sorts the expected oil well fracturing effect according to the size of comprehensive attribute value, then selects construction well according to the sort results. In this way, it not only solves the difficulty to accurately resolve fracture height of analytical method and problem of large calculation of numerical method, also provides a simple and practical method for live well selection. According to fracturing selection of Changqing oil field 5 wells and on-site application comparison of 2 wells, it is consistent with the prediction result.
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Cai, Bo, Yun Hong Ding, Yong Jun Lu, Chun Ming He, and Gui Fu Duan. "Leak-Off Coefficient Analysis in Stimulation Treatment Design." Advanced Materials Research 933 (May 2014): 202–5. http://dx.doi.org/10.4028/www.scientific.net/amr.933.202.
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Hydraulic fracturing was first used in the late 1940s and has become a common technique to enhance the production of low-permeability formations.Hydraulic fracturing treatments were pumped into permeable formations with permeable fluids. This means that as the fracturing fluid was being pumped into the formation, a certain proportion of this fluid will being lost into formation as fluid leak-off. Therefore, leak-off coefficient is the most leading parameters of fracturing fluids. The accurate understanding of leak-off coefficient of fracturing fluid is an important guidance to hydraulic fracturing industry design. In this paper, a new field method of leak-off coefficient real time analysis model was presented based on instantaneous shut-in pressure (ISIP). More than 100 wells were fractured using this method in oil field. The results show that average liquid rates of post-fracturing was 22m3/d which double improvement compared with the past treatment wells. It had an important role for hydraulic fracturing stimulation treatment design in low permeability reservoirs and was proven that the new model for hydraulic fracturing treatment is greatly improved.
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Panikarovski, V. V., E. V. Panikarovski, and S. K. Sohoshko. "USE OF FORMATION HYDRAULIC FRACTURING FOR OIL RECOVERY ENHANCEMENT." Oil and Gas Studies, no. 4 (August 30, 2015): 76–80. http://dx.doi.org/10.31660/0445-0108-2015-4-76-80.
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The article briefly reviews the conduction of jobs aimed at intensification of influx and improvement of oil recovery of the layer VK in the field Krasnoleninskoye. The analysis is made of FHF technology to select the wells for FHF implementation in the development well stock under operation in the Em-Yogov area of the said field. Based on the structure of residual reserves a decision was made about the necessity to perform FHF in the low productive reservoirs.
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Barati, Reza, and Jenn-Tai Liang. "A review of fracturing fluid systems used for hydraulic fracturing of oil and gas wells." Journal of Applied Polymer Science 131, no. 16 (April 7, 2014): n/a. http://dx.doi.org/10.1002/app.40735.
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Panikarovskii, E. V., V. V. Panikarovskii, M. M. Mansurova, and M. V. Listak. "Application of multi-stage hydraulic fracturing in the development of Achimov sediments at the Urengoy oil and gas condensate field." Oil and Gas Studies, no. 2 (June 2, 2020): 38–48. http://dx.doi.org/10.31660/0445-0108-2020-2-38-48.
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The development of deep-lying Achimov deposits makes it possible to extract additional volumes of gas and gas condensate in the fields with decreasing production, as well as implement strategies to introduce new methods to increase oil, gas and condensate production. The decrease in well productivity during the development of gas condensate fields requires the use of new methods of intensification of production. The main method for increasing the productivity of Achimov wells is hydraulic fracturing. The choice of hydraulic fracturing technology for low-permeability Achimov deposits is especially important for creating large hydraulic fractures and high permeability, as well as maintaining the filtration characteristics of reservoir rocks. Multi-stage hydraulic fracturing is the most effective method of intensifying gas and gas condensate production in the development of the Achimov deposits.
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Sherwood, Owen A., Jessica D. Rogers, Greg Lackey, Troy L. Burke, Stephen G. Osborn, and Joseph N. Ryan. "Groundwater methane in relation to oil and gas development and shallow coal seams in the Denver-Julesburg Basin of Colorado." Proceedings of the National Academy of Sciences 113, no. 30 (July 11, 2016): 8391–96. http://dx.doi.org/10.1073/pnas.1523267113.
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Unconventional oil and gas development has generated intense public concerns about potential impacts to groundwater quality. Specific pathways of contamination have been identified; however, overall rates of contamination remain ambiguous. We used an archive of geochemical data collected from 1988 to 2014 to determine the sources and occurrence of groundwater methane in the Denver-Julesburg Basin of northeastern Colorado. This 60,000-km2 region has a 60-y-long history of hydraulic fracturing, with horizontal drilling and high-volume hydraulic fracturing beginning in 2010. Of 924 sampled water wells in the basin, dissolved methane was detected in 593 wells at depths of 20–190 m. Based on carbon and hydrogen stable isotopes and gas molecular ratios, most of this methane was microbially generated, likely within shallow coal seams. A total of 42 water wells contained thermogenic stray gas originating from underlying oil and gas producing formations. Inadequate surface casing and leaks in production casing and wellhead seals in older, vertical oil and gas wells were identified as stray gas migration pathways. The rate of oil and gas wellbore failure was estimated as 0.06% of the 54,000 oil and gas wells in the basin (lower estimate) to 0.15% of the 20,700 wells in the area where stray gas contamination occurred (upper estimate) and has remained steady at about two cases per year since 2001. These results show that wellbore barrier failure, not high-volume hydraulic fracturing in horizontal wells, is the main cause of thermogenic stray gas migration in this oil- and gas-producing basin.
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Crawford, Mark. "H2O Taking the Hydro out of Hydraulic Fracturing." Mechanical Engineering 137, no. 03 (March 1, 2015): 30–35. http://dx.doi.org/10.1115/1.2015-mar-1.
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This paper demonstrates the increasing use of waterless methods in oil and gas industry. Waterless methods aim to make unconventional oil and gas well more environmental friendly. While waterless fracturing is still relatively rare in the United States, it is more common in operations north of the border. Gas-energized fracturing has a significant advantage over traditional water-based methods: it requires less proppant, which saves money, and it can double oil and gas recovery from a well. Praxair, a supplier of industrial gases based in Danbury, Conn., has developed a system that relies on a different liquefied gas. Its DryFrac technology relies on liquid carbon dioxide that is mixed with sand and sent down the hole under high pressure. The experts point out that in places where hydraulic fracturing’s water use is becoming a real constraint to exploiting shale formations, it is likely that petroleum companies will find that it is worth it to make the commitment to waterless fracturing.
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SHARAFUTDINOV, Ramil F., and Filyus F. Davletshin. "AN ANALYTICAL MODEL OF A NON-STATIONARY TEMPERATURE FIELD IN A RESERVOIR WITH A HYDRAULIC FRACTURING." Tyumen State University Herald. Physical and Mathematical Modeling. Oil, Gas, Energy 7, no. 2 (2021): 75–94. http://dx.doi.org/10.21684/2411-7978-2021-7-2-75-94.
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At the present stage of development of the oil and gas industry, considerable attention is paid to methods of increasing oil recovery of productive reservoirs. One of the most popular methods of intensifying oil production today is hydraulic fracturing. The efficiency and success of hydraulic fracturing largely depends on the parameters of the formed fracture; in this regard, the development of methods for evaluating the parameters of hydraulic fracturing fractures is an urgent task. Non-stationary thermometry is a promising area for monitoring the quality of hydraulic fracturing. To date, thermometry is used to localize the locations of multiple fractures in horizontal wells. In this paper, we study the application of non-stationary thermometry for estimating the parameters of a vertical hydraulic fracturing fracture. An analytical model of non-isothermal single-phase fluid filtration in a reservoir with a vertical fracture is developed. To calculate the temperature field in the formation and the fracture, the convective heat transfer equation is used, taking into account the thermodynamic effects (Joule — Thomson and adibatic), for the fracture, the heat and mass transfer between the fracture and the formation area is also taken into account. To assess the correctness of the model, the analytical solution is compared with the results of numerical modeling in the Ansys Fluent software package. The nonstationary temperature field is calculated for the constant sampling mode. It is established that at the initial moment of time after the well start-up, a negative temperature anomaly is formed due to the adiabatic effect, the value of which increases with a decrease in the fracture width. Over time, the temperature of the fluid flowing into the well increases due to the Joule — Thomson effect, and the value of the positive temperature anomaly increases as the width and permeability of the fracture decreases due to an increase in the pressure gradient in it. The developed analytical model can be used to solve inverse problems for estimating hydraulic fracturing parameters based on non-stationary temperature measurements in the wellbore of producing wells.
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Mulyavin, S. F., and R. A. Neschadimov. "Features of development of US1 object at the oil field X." Oil and Gas Studies, no. 6 (January 15, 2021): 49–59. http://dx.doi.org/10.31660/0445-0108-2020-6-49-59.
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The oil field X belongs to the category of large in terms of initial recoverable reserves, multi-layer and complex in geological structure. The US1 object accounts for 20,3 % of the initial recoverable reserves, while the selection from the initial recoverable reserves is only 11,4 %, this makes object the most promising from the point of planning further development of the field. The analysis presented in the article is aimed at identifying problems and features of the development. During the analysis, we noted low reservoir properties of the object, high watercut of the produced products, the deterioration of the energy state of the deposits, which manifests itself in the form of a decrease in dynamic levels and a decrease in fluid flow rate. Drilling of wells, both production and injection, was carried out using hydraulic fracturing technology. Given the fact that the deposits of the US1 object are closed, lithological shielded and are characterized by the absence of an oil-water zone, the watering of wells, according to the our opinion, is associated with pulling up water from the underlying water-saturated formation as a result of the propagation of cracks obtained during hydraulic fracturing. The reason for the deterioration of the energy state is the commissioning of injection wells using hydraulic fracturing and the withdrawal of water through hydraulic fracture in the underlying formation.
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DOSZHANOV, M. ZH, B. N. ALYBAEV, M. K. KARAZHANOVA, D. A. AKHMETOV, and G. ZH TASBOLAT. "ANALYSIS OF THE DEVELOPMENT OF AUTO-HYDRAULIC FRACTURES ON WATER INJECTION WELLS." Neft i gaz 1, no. 121 (April 15, 2020): 69–76. http://dx.doi.org/10.37878/2708-0080/2021-1.05.
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As the experience of field development shows, the unplanned growth of cracks in injection wells does not always have a positive effect on the development of oil reserves, but on the contrary, causes premature flooding of producing wells. At present, most of the fields are in the final stage of development, and increasing the coverage of the reservoir by flooding is an important task for the development of oil fields. The article considers and analyzes the influence of injection wells on the growth of hydraulic fracturing cracks and the relationship with oil production on the example of the Karazhanbas field (hereinafter referred to as the KBM).
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Liu, Quansheng, Lei Sun, Pingli Liu, and Lei Chen. "Modeling Simultaneous Multiple Fracturing Using the Combined Finite-Discrete Element Method." Geofluids 2018 (2018): 1–20. http://dx.doi.org/10.1155/2018/4252904.
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Simultaneous multiple fracturing is a key technology to facilitate the production of shale oil/gas. When multiple hydraulic fractures propagate simultaneously, there is an interaction effect among these propagating hydraulic fractures, known as the stress-shadow effect, which has a significant impact on the fracture geometry. Understanding and controlling the propagation of simultaneous multiple hydraulic fractures and the interaction effects between multiple fractures are critical to optimizing oil/gas production. In this paper, the FDEM simulator and a fluid simulator are linked, named FDEM-Fluid, to handle hydromechanical-fracture coupling problems and investigate the simultaneous multiple hydraulic fracturing mechanism. The fractures propagation and the deformation of solid phase are solved by FDEM; meanwhile the fluid flow in the fractures is modeled using the principle of parallel-plate flow model. Several tests are carried out to validate the application of FDEM-Fluid in hydraulic fracturing simulation. Then, this FDEM-Fluid is used to investigate simultaneous multiple fractures treatment. Fractures repel each other when multiple fractures propagate from a single horizontal well, while the nearby fractures in different horizontal wells attract each other when multiple fractures propagate from multiple parallel horizontal wells. The in situ stress also has a significant impact on the fracture geometry.
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Gharibi, Abdoullatif, Mansoor Zoveidavianpoor, and Farshad Daraei Ghadikolaei. "On the Application of Well Stimulation Method in Improvement of Oil Recovery." Applied Mechanics and Materials 735 (February 2015): 31–35. http://dx.doi.org/10.4028/www.scientific.net/amm.735.31.
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Hydraulic Fracturing, Proppant, Acid FracturingAbstract. Increase in the price of oil and gas during recent years have motivated oil and gas companies to focus on the methods that lead to increasing in the oil and gas production. Oil well stimulation as one of these methods includes a variety of operations that performed to improve productivity of the well. The main objective of a stimulation treatment is to increase the rate at which the formation delivers hydrocarbons naturally. Today’s well stimulation method is converted to the appropriate method in the oil and gas industry to maintain or increase of well productivity. Injection of acid to partially dissolve the rock, and hydraulic fracturing to split the rock and prop it open with proppant are two common techniques for stimulating of the wells. Deciding about selection of the best method for stimulation of the wells is related to the comprehensive evaluation of capabilities of each technique and conditions which are governed on specific job intended. In this article, we are trying to present a description about well stimulation method, methods that are employed to execute well stimulation, and application of these different techniques for stimulating of wells.
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Panikarovskii, Evgeny V., Valentin V. Panikarovskii, and Alexandra E. Anashkina. "Vankor oil field development experience." Oil and Gas Studies, no. 1 (April 4, 2019): 47–51. http://dx.doi.org/10.31660/0445-0108-2019-1-47-51.
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The Vankor oil field is in the third stage of the development. Well stock mostly includes horizontal and directional wells. Analysis of the field development showed that actual development rate is much higher than planned. Energy potential of the field is drained out due to formation pressure decline and water flooding. New technologies for restoring well productivity, such as acid treatment and hydraulic fracturing should be introduced to maintain planned development rate. Drilling multilateral wells should be used as main enhanced oil recovery technique.
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Raimi, Daniel. "Comment on “The intensification of the water footprint of hydraulic fracturing”." Science Advances 6, no. 8 (February 2020): eaav2110. http://dx.doi.org/10.1126/sciadv.aav2110.
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Kondash et al. provide a valuable contribution to our understanding of water consumption and wastewater production from oil and gas production using hydraulic fracturing. Unfortunately, their claim that the water intensity of energy production using hydraulic fracturing has increased in all regions is incorrect. More comprehensive data show that, while the water intensity of production may have increased in regions such as the Permian basin, it has decreased by 74% in the Marcellus and by 19% in the Eagle Ford region. This error likely stems from an improper method for estimating energy production from wells: The authors use the median well to represent regional production, which systematically underestimates aggregate production volumes. Across all regions, aggregate data suggest that the water intensity of oil and natural gas production using hydraulic fracturing has increased by 19%. There also appears to be an error in estimates for water consumption in the Permian basin.
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Zhang, Hai Yong, Shun Li He, Dai Hong Gu, Guo Hua Luan, Cheng Quan Men, Shao Yuan Mo, and Gang Lei. "Influence of Perforating Parameters on the Productivity of Fractured Well in Tight Reservoir." Advanced Materials Research 848 (November 2013): 92–95. http://dx.doi.org/10.4028/www.scientific.net/amr.848.92.
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Hydraulic fracturing is an effective measure to increase oil production for the development of low permeability reservoir. The selection of perforating parameters has a direct effect on the fracture expansion, formation fracture cracking pressure and even the implementation success of fracturing in that the fracturing processing fluid and artificial fracture all need to pass through the extension of perforation. In field application, the selection of perforating parameters is usually determined base on experience without combining with the actual data of the hydraulic fracturing wells. This work focuses on analyzing the influence of perforating parameters on the productivity of fractured well based on an established productivity prediction model through analytical method.Results show that, take a specific area of Changqing oil field for example, the perforation diameter has little effect on the productivity after fracturing, the other optimized perforating parameters are as follows: the perforation degree 30~40%, perforation density 8~12 perforation per meter, perforation depth 0.2~0.3m. The results are helpful to guide the optimization of perforating parameters in low permeability reservoir.
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Sumner, Andrew J., and Desiree L. Plata. "A geospatially resolved database of hydraulic fracturing wells for chemical transformation assessment." Environmental Science: Processes & Impacts 22, no. 4 (2020): 945–55. http://dx.doi.org/10.1039/c9em00505f.
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A database to unify physicochemical parameters of oil and gas wells with chemical additive disclosures helps highlight chemical transformation potential across the United States with geospatial specificity, informing improved industrial practice and environmental assessment.
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Li, Jianxiong, Wen Xiao, Guanzhong Hao, Shiming Dong, Wen Hua, and Xiaolong Li. "Comparison of Different Hydraulic Fracturing Scenarios in Horizontal Wells Using XFEM Based on the Cohesive Zone Method." Energies 12, no. 7 (March 31, 2019): 1232. http://dx.doi.org/10.3390/en12071232.
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Multistage hydraulic fracturing is a highly effective method for creating multiple transverse fractures to improve gas and oil reservoir production. It is critical to minimize the fracture spacing while also ensuring transverse propagation of fractures in multi-fractured horizontal wells. In this paper, a 3D fully coupled pore pressure-stress model based on the extended finite element method (XFEM) combined with the cohesive zone method is established to simulate five different fracturing scenarios in close spacing. The sensitivity of mesh size and the integration method are optimal, which are verified by the highly accurate traditional cohesive zone method. Then, the effect of five different fracturing scenarios on fracture geometries is compared. It is shown that spacing is a key parameter controlling fracture geometries in all fracturing scenarios. Alternative sequential and modified two-step fracturing can significantly reduce the influence of stress shadowing to generate more transverse fractures and form longer effective fractures. The sequential and two-step fracturing see an obvious improvement with increased fracture effective length when the spacing increases. The simultaneous fracturing technique can result in excessive closure of the middle fractures, which causes serious insertion of proppants. These results offer a new insight on optimization of hydraulic fracturing and can be a guidance for typical field cases.
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Helmi, Mia Ferian, Muhammad Zakiy Y., Dinar Kaesti, Maulida Aulia Fadhina, and Anisa Novia Risky. "Analysis of the Difference between Hydraulic Fracturing and Flow Channel Fracturing." Journal of Petroleum and Geothermal Technology 1, no. 1 (July 17, 2020): 1. http://dx.doi.org/10.31315/jpgt.v1i1.3320.
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As time goes by, there will be a decline in formation productivity, as reflected in the decline in the rate of oil production from production wells. The decline in the rate of production was caused by many things such as a decrease in reservoir pressure, also formation damage. Where damage to the formation will result in a decrease in rock permeability. The decrease in rock permeability is caused by the blockage of rock pores due to the invasion of solids and drill mud filtrate, cementing, fluid fluids or previous stimulation. Besides the small rate of oil production can also be caused by the low natural permeability of rocks. With the decreasing productivity of the formation, it is necessary to make efforts to increase the productivity of the formation again, where one of them is by the method of hydraulic fracture stimulation. In this analysis, we will discuss the difference between conventional stimulation methods and flow channel fracturing. Flow channel fracturing is a fracturing process by making a network around proppant granules to form proppant pillar, so that a path is formed for the fluid to flow more easily. What distinguishes between conventional hydraulic fracturing with flow channel fracturing is the resulting fracture form, fracturing fluid injection pattern, and the amount of proppant used.
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Yu, Long, Jinjie Wang, Chong Wang, and Daixin Chen. "Enhanced Tight Oil Recovery by Volume Fracturing in Chang 7 Reservoir: Experimental Study and Field Practice." Energies 12, no. 12 (June 24, 2019): 2419. http://dx.doi.org/10.3390/en12122419.
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The Chang 7 reservoir in Changqing oilfield is rich in tight oil. However, due to the low formation permeability, it is very difficult to obtain economical oil production without stimulation treatments. Volume fracturing seems to be a more efficient tight oil recovery enhancement (EOR) method in Chang 7 pilot tests compared with conventional hydraulic fracturing. In this study, Chang 7 tight oil reservoir was first characterized by its geological property, hydrocarbon source rock distribution, and formation physiochemical property. Tight core flooding tests were then conducted to experimentally investigate the EOR ability of the volume fracturing technique. The field-scale practice was also demonstrated and analyzed. The results show that Chang 7 reservoir is favorable for the generation of a large amount of tight oil. Fractures created in tight cores can significantly improve the fluid flow conductivity and enhance the imbibition of displacing water, resulting in a greater tight oil recovery increment. Volume fracturing is an effective way to generate a larger number of fractures. Field application indicates that volume fracturing treatment can form a much greater reservoir stimulation volume. Daily oil production in the volume-fracturing-treated wells can be more than twice as high as that in the conventional-fracturing-treated wells.
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Ovchinnikov, V. P., O. V. Rozhkova, S. N. Bastrikov, D. S. Leontiev, and P. V. Ovchinnikov. "Technological solutions for well construction in high-viscous shale hydrocarbon fields." Oil and Gas Studies, no. 3 (July 15, 2021): 52–62. http://dx.doi.org/10.31660/0445-0108-2021-3-52-62.
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The article discusses the main technological processes of well construction for the production of high-viscosity hydrocarbons from productive lowporosity reservoirs with high temperature and pressure conditions, which include shale deposits of Bazhenov formation. According to the results of the review and analysis of existing solutions in the development of this deposits, the following measures were justified and proposed: construction of branched multi-hole azimuth horizontal wells, implementation of selective multi-stage hydraulic fracturing in the productive formation; the use of oil-based process fluids when opening the reservoir, the use of plugging materials for isolation of the reservoir, the hardening product of which is represented by thermally stable hydrate phases (hydrobasic hydrosilicates). Вranched wells have a long horizontal end (about 1 000 meters or more). Only a part of the horizontal section works effectively, which is the basis for the development and application of the staged, both in time and along the strike, hydraulic fracturing method. At the level of the invention, a method and apparatus for carrying out multistage selective hydraulic fracturing in wells with horizontal completion have been developed. The article describes a method for implementing multistage selective hydraulic fracturing, comparing this method with the existing ones. Much attention is given to the need to use hydrocarbon-based solutions for the initial opening the reservoir, to use cement slurries from composite materials to separate the reservoir, the hardening product of which is a stone formed by low-basic calcium hydrosilicate.
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Parekh, Siddharth, Ali Pilehvari, and Robert Serth. "Prediction of Fluid Behavior Using Generalized Hydraulic Calculation Method in Hydraulic Fractures." Journal of Advanced Research in Fluid Mechanics and Thermal Sciences 81, no. 1 (March 5, 2021): 120–30. http://dx.doi.org/10.37934/arfmts.81.1.120130.
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Hydraulic fracturing has been used as one of the stimulation techniques to economically increase oil and gas production by creating small cracks in subsurface geologic formations to allow oil or gas to move toward a producing well. Hydraulics plays a vital role in many oil field operations including drilling, completion, fracturing and production. In the case of fracturing, however, the role of hydraulics becomes important since optimized hydraulics can minimize the cost and conversely, any miscalculations may cause problems such as the fluid loss or may potentially even lead to loss of the well. The current methods of the hydraulic calculation for non-Newtonian fluids necessitate determination of the robust model. This paper presented a new method for calculating pressure losses in the hydraulic fractures. The objective of this study was to develop the generalized model for hydraulic calculation for non-Newtonian fluid and run the case studies for the model validation. In the present work, detailed algorithm for the hydraulic calculation has been developed and then programmed in C++. The only input to the program is the raw rheological data, shear stress versus shear rate and the geometrical characteristics of the slit. Model validation with the new method has established a very small percentage difference between the values predicted by the model and experimental data. The results demonstrate that the new method is accurately predicting the pressure drop in both laminar and turbulent flow regimes. It is shown that the fluid behavior is more accurately represented using the new method than that with the standard fluid models available in the petroleum industry. Further validation and development to be carried out using experimental data for variety of fluid types.
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Sodi, Jakfar, Dyah Rini Ratnaningsih, and Dedy Kristanto. "Evaluation And Optimization Production Of Low Permeability Carbonate Reservoir By Hydraulic Fracturing In “Jaso Field”." Journal of Petroleum and Geothermal Technology 2, no. 1 (May 28, 2021): 11. http://dx.doi.org/10.31315/jpgt.v2i1.4143.
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“Jaso field” is located the South Sumatra basin, Indonesia. The lithology of this field is dominated by limestone / carbonate reservoirs with varying permeability (low / tight to high / porous). Acid Fracturing stimulation has been applied to develop this field, because in ideal conditions (with the solubility test between acid and formation > 80%) wormholes will be made in the formation to increase reservoir conductivity and productivity. However, in the Jaso oil field, in some special cases, acid injection did not provide satisfactory results for increasing well conductivity and productivity.In this thesis, we conduct research and evaluation of wells in Jaso field. For example: JS-28, JS-11 and JS-40 are oil wells in the Jaso field with low / narrow reservoir permeability and production rates. Stimulation has been carried out in the JS-28 well, but the results are still below the acid expectation even though the intermediate solubility test (solubility test) is more than 88%.Hydraulic Fracturing with the sandfracturing method (injecting sand proppant with high pressure and exceeding the gradient fracture) has been successfully applied to three wells in the Jaso Field by increasing the oil production rate by more than 100 bopd per well. With this case study, we find that the application of hydraulic fracturing (sandfracturing) with thrusters is not limited to sandstone / sandstone reservoirs, but that this method can be successfully applied to increase the conductivity and productivity of carbonate reservoirs (in special cases) taking into account several parameters of integrity. reservoir wells and characteristics.
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Askerov, A. A., S. G. Panyak, T. Yu Yusifov, and E. Yu Yusifov. "REORIENTATION OF FRACTURES DIRECTION AFTER THE REPEATED FORMATION HYDRAULIC FRACTURING." Oil and Gas Studies, no. 2 (April 30, 2015): 39–41. http://dx.doi.org/10.31660/0445-0108-2015-2-39-41.
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The article describes the experience of implementation of repeated FHF with reducing the proppant mass in the fields of LLC “RN-Purneftegas”. A new approach is justified towards performing the repeated FHF in wells where a risk of the fracture breakthrough into the injected water front remains. The pilot operations proved a possibility and necessity of reduction of proppant amount used at repeated FHF run for additional recovery of oil reserves at a later stage of wells development.
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Turley, Bethani, and Martina Angela Caretta. "Household Water Security: An Analysis of Water Affect in the Context of Hydraulic Fracturing in West Virginia, Appalachia." Water 12, no. 1 (January 3, 2020): 147. http://dx.doi.org/10.3390/w12010147.
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Hydraulic fracturing has been booming in the last decade in the United States. While natural gas extraction and production has improved the national energy security, it has raised questions around the water security of those communities where extraction is taking place. Both scientists and residents are concerned about hydraulic fracturing’s impacts on surface- and groundwater, especially regarding how hydraulic fracturing impacts residents’ access to safe household well water. In the past decade, the Marcellus Shale has been developed in Northwestern West Virginia, yet the human geography dimensions of oil and gas extraction in West Virginia remain to be investigated. This article, based on 30 in-depth interviews, explores household groundwater insecurity due to hydraulic fracturing experienced by residents (i.e., mineral owners, surface owners, and concerned citizens) in Northwestern West Virginia. The concept of water affect is used to attend to the emotional and subjective dimensions of water security by unveiling the power, emotional struggles, and mental stress inherent in water testing practices and environmental regulation around hydraulic fracturing. Water testing is typically conducted by contractors hired by oil and gas companies, but it is mired in delayed test results and incorrect testing procedures, triggering residents’ negative feelings toward oil and gas companies. This article furthers the understanding of water security, commonly defined in terms of individual access to adequate water quality and quantity, by studying Appalachian residents’ anxieties about well water contamination and uncertainty around the long-term water impacts of hydraulic fracturing. By investigating the uneven power relations around groundwater in West Virginia, the emotional experiences and responses are articulated to further the notion of water affect as impacting household groundwater security.
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Yang, Jiao. "Fracturing Proppant Evaluation and Economic Optimization in Daqing Oilfield." Defect and Diffusion Forum 394 (August 2019): 63–67. http://dx.doi.org/10.4028/www.scientific.net/ddf.394.63.
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Fracturing proppant is an important material for hydraulic fracturing, and its performancehas an important impact on the fracturing effect and the fracturing life of oil and gas wells. On thepremise of satisfying the reservoir reconstruction requirement, optimizing the proppant with the besteconomic benefit can reduce the cost of the fracturing operation. The flow conductivity and brokenrate of common proppants are tested to obtain the performance boundaries. Based on the proppantevaluation, according to the selection method, the optimal proppant type for different formationpressures can be selected to maximize economic benefits.
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Haiyang, Yu, Ji Wenjuan, Luo Cheng, Lu Junkai, Yan Fei, Liu Yi, and Wu Jun. "A new slick water system for hydraulic fracturing in tight reservoir to enhance imbibition oil recovery." E3S Web of Conferences 303 (2021): 01001. http://dx.doi.org/10.1051/e3sconf/202130301001.
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In order to give full play to the role of imbibition of capillary force and enhance oil recovery of ultralow permeability sandstone reservoir after hydraulic fracturing, the mixed water fracture technology based on functional slick water is described and successfully applied to several wells in oilfield. The core of the technology is determination of influence factors of imbibition oil recovery, the development of new functional slick water system and optimization of volume fracturing parameters. The imbibition results show that it is significant effect of interfacial tension, wetting on imbibition oil recovery. The interfacial tension decreases by an order of magnitude, the imbibition oil recovery reduces by more than 10%. The imbibition oil recovery increases with the contact angle decreasing. The emulsifying ability has no obvious effect on imbibition oil recovery. The functional slick water system considering imbibition is developed based on the solution rheology and polymer chemistry. The system has introduced the active group and temperature resistant group into the polymer molecules. The molecular weight is controlled in 1.5 million. The viscosity is greater than 2mPa·s after shearing 2h under 170s-1 and 100℃. The interfacial tension could decrease to 10-2mN/m. The contact angle decreased from 58° to 22° and the core damage rate is less than 12%. The imbibition oil recovery could reach to 43%. The fracturing process includes slick water stage and linear gel stage. 10% 100 mesh ceramists and 8% temporary plugging agents are carried into the formation by functional slick water. 40-70 mesh ceramists are carried by linear gel. The liquid volume ratio is about 4:1 and the displacement is controlled at 10-12m3/min. The sand content and fracturing fluid volumes of single stage are 80m3 and 2500 m3 respectively. Compared with conventional fracturing, due to imbibition oil recovery, there is only 25% of the fracturing fluid flowback rate when the crude oil flew out. When the oil well is in normal production, about 50% of the fracturing fluid is not returned. It is useful to maintain the formation energy and slow down the production decline. The average cumulative production of vertical wells is greater than 2800t, and the effective period is more than 2 years. This technology overcoming the problem of high horizontal stress difference and lack of natural fracture has been successfully applied in Jidong Oilfield ultralow permeability reservoir. The successful application of this technology not only helps to promote the effective use of ultralow permeability reservoirs, but also helps to further clarify the role of imbibition recovery, energy storage and oil-water replacement mechanism.
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Petrichenko, Mikhail, Nikolay Vatin, Darya Nemova, Nikita Kharkov, and Anastasiia Staritcyna. "EOR (Oil Recovery Enhancement) Technology Using Shock Wave in the Fluid." Applied Mechanics and Materials 627 (September 2014): 297–303. http://dx.doi.org/10.4028/www.scientific.net/amm.627.297.
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In this research the alternative method is presented increases of oil recovery of an oil collector. Shock wave impact on layer. The technology is developed, advantage of this method is shown in comparison with layer hydraulic fracturing. For increase oil recovery and restoration of wells the traditional is widely applied technology of hydraulic fracturing of layer (flyuding), allowing on the short period to recover a well. Sense of a flyuding that hydrostatic pressure is created is considerable exceeding mountain and bringing to a rupture of a collector on one or several cracks. In this work the alternative technique of increase in oil recovery is offered by creation of a shock wave small intensity in the bottom fluid. With a high frequency of repeatability set of blows increases quantity of micro cracks in collector rock, increasing coefficient of permeability of layer without breaking its connectivity.
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Arguello-Marrufo, Pedro L., Dennys A. Lopez-Falcon, and Laura Munoz-Salazar. "Production optimization and economic analysis for hydraulic fracturing operations in tight oil wells." Petroleum Science and Technology 39, no. 11-12 (March 30, 2021): 381–91. http://dx.doi.org/10.1080/10916466.2021.1905663.
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Krivova, N. R. "Improvement of oil production in low permeability deposits with a system of horizontal wells." Revista de la Universidad del Zulia 11, no. 29 (February 8, 2020): 205–16. http://dx.doi.org/10.46925//rdluz.29.13.
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The article describes an approach to the production of difficult to extract oil, confined to deposits with low poroperm properties, using a system of horizontal wells and hydraulic multistage fracturing. The main problems that arise during the development of the well are analyzed. A conclusion is reached on the possibility of continuing to apply the method based on the analysis of pilot tests.
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Qu, Zhanqing, Jiwei Wang, Tiankui Guo, Lin Shen, Hualin Liao, Xiaoqiang Liu, Jiacheng Fan, and Tong Hao. "Optimization on fracturing fluid flowback model after hydraulic fracturing in oil well." Journal of Petroleum Science and Engineering 204 (September 2021): 108703. http://dx.doi.org/10.1016/j.petrol.2021.108703.
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Silva, G. B., L. O. A. Rojas, and J. A. Soares. "HYDRAULIC FRACTURING OF AN ARENITIC RESERVOIR BASED IN THE PERKINS-KERN MODEL USING A STIMPLAN SIMULATOR." Brazilian Journal of Petroleum and Gas 15, no. 1-2 (June 25, 2021): 1–12. http://dx.doi.org/10.5419/bjpg2021-0001.
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Hydraulic fracturing consists of a technique capable of stimulating oil wells that have suffered a decline in production over time. It also allows the production in reservoirs that have low permeability through the creation of a network of channels in the rock. In this context, this article aims to numerically simulate the hydraulic fracturing applied in a sandstone reservoir according to data extracted from an oil well located in the Aracaju City field of the Sergipe-Alagoas Basin. To complete this study, a geological model of the reservoir was generated. Subsequently, a fracture was created in the rock-reservoir in a controlled manner using the Perkins and Kern fracture model. Results show that the fracture takes a satisfactory proportion in the reservoir rock, reaching a depth of penetration equivalent to 695.7 meters.
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Lu, Cong, Li Ma, Zhili Li, Fenglan Huang, Chuhao Huang, Haoren Yuan, Zhibin Tang, and Jianchun Guo. "A Novel Hydraulic Fracturing Method Based on the Coupled CFD-DEM Numerical Simulation Study." Applied Sciences 10, no. 9 (April 26, 2020): 3027. http://dx.doi.org/10.3390/app10093027.
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For the development of tight oil reservoirs, hydraulic fracturing employing variable fluid viscosity and proppant density is essential for addressing the problems of uneven placement of proppants in fractures and low propping efficiency. However, the influence mechanisms of fracturing fluid viscosity and proppant density on proppant transport in fractures remain unclear. Based on computational fluid dynamics (CFD) and the discrete element method (DEM), a proppant transport model with fluid–particle two-phase coupling is established in this study. In addition, a novel large-scale visual fracture simulation device was developed to realize the online visual monitoring of proppant transport, and a proppant transport experiment under the condition of variable viscosity fracturing fluid and proppant density was conducted. By comparing the experimental results and the numerical simulation results, the accuracy of the proppant transport numerical model was verified. Subsequently, through a proppant transport numerical simulation, the effects of fracturing fluid viscosity and proppant density on proppant transport were analyzed. The results show that as the viscosity of the fracturing fluid increases, the length of the “no proppant zone” at the front end of the fracture increases, and proppant particles can be transported further. When alternately injecting fracturing fluids of different viscosities, the viscosity ratio of the fracturing fluids should be adjusted between 2 and 5 to form optimal proppant placement. During the process of variable proppant density fracturing, when high-density proppant was pumped after low-density proppant, proppants of different densities laid fractures evenly and vertically. Conversely, when low-density proppant was pumped after high-density proppant, the low-density proppant could be transported farther into the fracture to form a longer sandbank. Based on the abovementioned observations, a novel hydraulic fracturing method is proposed to optimize the placement of proppants in fractures by adjusting the fracturing fluid viscosity and proppant density. This method has been successfully applied to more than 10 oil wells of the Bohai Bay Basin in Eastern China, and the average daily oil production per well increased by 7.4 t, significantly improving the functioning of fracturing. The proppant settlement and transport laws of proppant in fractures during variable viscosity and density fracturing can be efficiently revealed through a visualized proppant transport experiment and numerical simulation study. The novel fracturing method proposed in this study can significantly improve the hydraulic fracturing effect in tight oil reservoirs.
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Crawford, Mark. "Fracturing Rocks to Unlock New Oil." Mechanical Engineering 135, no. 12 (December 1, 2013): 24–29. http://dx.doi.org/10.1115/1.2013-dec-1.
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This article discusses various uses and benefits of hydraulic fracturing technology in the field of oil industry. Engineers continue to increase hydraulic fracturing efficiency by developing better multistage stimulation systems. These systems enable treatment of many intervals along a horizontal wellbore with a minimum number of pull-outs, or even in a single continuous operation. Many key advances in drilling and hydrofracturing have resulted from sophisticated modeling programs. Mechanical engineers play key roles in many aspects of hydrofracturing, especially the design of better down-hole tools, new materials, and improved numerical models. With the advances in modeling and real-time measurement, operators can deliver just the right type of fracking pressure, exactly where they want it, and repeat the process as needed, either in the same well, one that parallels it, or one that radiates out from the same central drill pad. The experts feel that if the world wishes to fully use its oil-and-gas resources, it will go hand-in-hand with hydraulic fracturing.
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Li, Yiqiang, and Junrong Liu. "Distributed FiberOptic Sensing for Hydraulic-Fracturing Monitoring and Diagnostics." E3S Web of Conferences 118 (2019): 02046. http://dx.doi.org/10.1051/e3sconf/201911802046.
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Fiber-optic sensing (FOS) are an emerging technology in hydraulic fracture diagnosis. Fiber-optic sensing technologies mainly include distributed temperature sensing (DTS) and distributed sound sensing (DAS). During hydraulic fracturing, the perforation cluster efficiency for cemented plug and perforation (PnP) wells, points of fracture initiation for packer and sleeve (PnS), and fluid channelling between fractured intervals caused by either tubular or annular leaks could be quantitatively evaluated by DTS data. Combined with DAS data, fluid distributions for each fracturing stage along the entire horizontal wellbore could be obtained. The roles of DTS and DAS in different hydraulic fracture stages are comprehensively analyzed in this paper. It provides a guidance for application of FOs in oil industry.
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Carpenter, Chris. "Fracturing With Height Control Extends the Life of Mature Reservoirs in the Pannonian Basin." Journal of Petroleum Technology 73, no. 01 (January 1, 2021): 53–54. http://dx.doi.org/10.2118/0121-0053-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 200588, “Fracturing With Height Control Extends the Life of Mature Reservoirs: Case Studies From the Pannonian Basin,” by Ruslan Malon, SPE, Independent, and Jonathan Abbott, SPE, and Ludmila Belyakova, SPE, Schlumberger, et al., prepared for the 2020 SPE Europec featured at the 82nd EAGE Conference and Exhibition, originally scheduled to be held in Amsterdam, 1-3 December. The paper has not been peer reviewed. Hydraulic proppant fracturing is an effective tool in mature, low-permeability reservoirs found in the Pannonian Basin. However, for wells already producing with high water cut, even a small fracture extension into a water-bearing zone offsets the gains in hydrocarbon production. Fracture-geometry-control (FGC) techniques limit increases in water cut. The complete paper describes the first implementation of a solution to control fracture height for conventional wells in the Pannonian Basin. An integrated engineering approach was applied, including a new proppant-transport model to predict fracture geometry improvement using the FGC solution. Decreased Recovery in A and B Fields Oilfield A began producing in 1984. In addition to an interruption by the war in Yugoslavia in the 1990s, production has been in decline, and most wells are at risk of being shut in because of low production rates. During the last 10 years, propped fracturing was integrated into the production strategy for this mature field. Field A comprises Lower Pontian (Miocene) sandstones. Another sandstone formation exists between 5 and 15 m below the production target reservoir, with high water saturation as confirmed by log analysis and well testing. The proximity of the oil target to the water-bearing interval still presents a risk to production considering that hydraulic fracturing is required to extend field life. An impermeable shale streak that may act as a geomechanical barrier exists below the target formation. With a lower risk of fracture propagation into the water zone, Field A was one of the first candidate fields for propped fracturing and was later considered for advanced fracture-height-control techniques to prevent the increase of water cut after stimulation. Hydraulic fracturing would not be trialed in Field B—the characteristics of which are provided in the complete paper—until the advanced height-control techniques had been proved on the basis of experience with Field A. Oilfield A: Early Fracturing Results Early campaigns proved the economic feasibility of propped fracturing, resulting in a 2.1-fold average increase in oil production during the first 6 months of production. Unfortunately, production after this early period declined rapidly. Increases in water cut, seen in several fracturing campaigns, clearly were related to hydraulic fracture growth. Although the resulting uplift in oil production warranted continued fracturing, avoiding water was a key issue to address before expansion of propped fracturing further in this field and to other fields with an even higher risk of water.
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Li, Guanqun, Yuliang Su, Yingchun Guo, Yongmao Hao, and Lei Li. "Frontier Enhanced Oil Recovery (EOR) Research on the Application of Imbibition Techniques in High-Pressure Forced Soaking of Hydraulically Fractured Shale Oil Reservoirs." Geofluids 2021 (July 28, 2021): 1–17. http://dx.doi.org/10.1155/2021/6634357.
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Shale reservoirs are characterized by low porosity and low permeability, and volume fracturing of horizontal wells is a key technology for the benefits development of shale oil resources. The results from laboratory and field tests show that the backflow rate of fracturing fluid is less than 50%, and the storage amount of fracturing fluid after large-scale hydraulic fracturing is positively correlated with the output of single well. The recovery of crude oil is greatly improved by means of shut-in and imbibition, therefore attracting increasing attention from researchers. In this review, we summarize the recent advances in the migration mechanisms and stimulation mechanisms of horizontal well high pressure forced soaking technology in the reservoirs. However, due to the diversity of shale mineral composition and the complexity of crude oil composition, the stimulation mechanism and effect of this technology are not clear in shale reservoir. Therefore, the mechanism of enhanced oil recovery by imbibition and the movable lower limit of imbibition cannot be characterized quantitatively. It is necessary to solve fragmentation research in the full-period fluid transport mechanisms in the follow-up research.
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Ibatullin, R. R. "Experience in North America Tight Oil Reserves Development. Horizontal Wells and Multistage Hydraulic Fracturing." Georesursy 19, no. 3 (2017): 176–81. http://dx.doi.org/10.18599/grs.19.3.4.
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Brownlow, Joshua W., Joe C. Yelderman, and Scott C. James. "Spatial Risk Analysis of Hydraulic Fracturing near Abandoned and Converted Oil and Gas Wells." Groundwater 55, no. 2 (September 27, 2016): 268–80. http://dx.doi.org/10.1111/gwat.12471.
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