Relevant bibliographies by topics / Oil wells – Hydraulic fracturing

Academic literature on the topic 'Oil wells – Hydraulic fracturing'

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Published: 4 June 2021
Last updated: 1 February 2022

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Journal articles on the topic "Oil wells – Hydraulic fracturing"

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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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Dissertations / Theses on the topic "Oil wells – Hydraulic fracturing"

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King, Jeremy Scott. "Acoustical signal during hydraulic fracturing." Morgantown, W. Va. : [West Virginia University Libraries], 1999. http://etd.wvu.edu/templates/showETD.cfm?recnum=565.

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Thesis (M.S.)--West Virginia University, 1999.
Title from document title page. Document formatted into pages; contains x, 82 p. : ill. (some col.) Vita. Includes abstract. Includes bibliographical references (p. 42).
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CACHAY, LEONARDO RODIN SALAS. "PROPPANT FLOWBACK IN OIL WELLS STIMULATED BY HYDRAULIC FRACTURING." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2004. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=6513@1.

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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO
Um dos principais objetivos da engenharia de petróleo é desenvolver e aplicar técnicas capazes de aumentar a produtividade de poços de petróleo, incluindo a estimulação da formação através de operações que aumentem a permeabilidade da rocha-reservatório e facilitem o escoamento do fluido. Dentre as técnicas de estimulação, a mais utilizada é o fraturamento hidráulico, a qual tem viabilizado a exploração em cerca de 40% dos poços produtores de petróleo em todo o mundo. Durante o fraturamento hidráulico, um material granular conhecido como material de sustentação ou propante, é injetado nas fraturas recém-criadas com o objetivo de mantê-las abertas e garantir-lhes condições de alta permeabilidade. A produção de material de sustentação (proppant flowback) é termo usado para descrever o refluxo do propante para o interior do poço, juntamente com o hidrocarboneto produzido. O controle do fluxo de propante representa um grave desafio para a indústria de petróleo, pois pode causar graves problemas operacionais e de segurança, relacionados com o desgaste dos equipamentos de produção, problemas econômicos associados ao custo de limpeza, paralisação das operações e intervenção no tratamento da fratura, problemas ambientais relacionados com a disposição de sólidos impregnados por hidrocarbonetos, etc. Neste contexto, a presente dissertação apresenta um estudo detalhado dos principais tipos de propante e de suas propriedades, bem como descreve os mecanismos que influem no refluxo do material de sustentação da fratura e analisa os principais modelos apresentados na literatura para previsão deste fenômeno. Uma retroanálise considerando os dados de campo em 22 poços da Petrobrás, localizados em Sergipe, permite uma comparação da eficiência entre quatro dos modelos, desenvolvidos com base em resultados de ensaios de laboratório, indicando suas vantagens e desvantagens para aplicação na prática da engenharia.
One of the main objectives of petroleum engineering is to develop and to apply techniques aiming the productivity increase of oil fields, including the stimulation of the rock through operations that increase the permeability of the oil reservoir and makes the flow of the fluid toward the well more efficient. Among the stimulation techniques, the most used is the hydraulic fracturing, carried out in about 40 percent of the producing oil wells around the world. During hydraulic fracturing, a granular material known as proppant, is injected into the just created fractures with the objective to keep them open and in order to guarantee the designed conditions of high permeability. Proppant flowback is the technical terminology employed to describe the flow of proppant from the fracture to the interior of the oil well, together with the produced hydrocarbon. An efficient and reliable control of this problem is still a major challenge to the oil industry, given the serious operational and security problems that it may cause, including costs of interrupted operations, cleaning measures, environmental contamination risks associated with the disposal of residues impregnated by oil, etc. In this context, the present thesis presents a detailed description on the main proppant materials and their engineering properties and available treatments, as well as on the physical mechanisms that control the flowback phenomenon. Several simple models published in the literature, that permit the forecast of proppant flowback in a fast and easy way, are also presented and discussed. Finally, a back-analysis considering the actual conditions in 22 Petrobras oil wells located in Sergipe was also carried out, what permitted a comparison among the results calculated according 4 prediction models, putting in evidence their advantages, shortcomings and adequacy as a design or control tool in the design and exploration of oil fields stimulated by hydraulic fracturing.
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Valencia, Karen Joy Petroleum Engineering Faculty of Engineering UNSW. "Optimising hydraulic fracture treatments in reservoirs under complex conditions." Awarded by:University of New South Wales. School of Petroleum Engineering, 2005. http://handle.unsw.edu.au/1959.4/23318.

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Growing global energy demand has prompted the exploitation of non-conventional resources such as Coal Bed Methane (CBM) and conventional resources such as gas-condensate reservoirs. Exploitation of these resources primarily depends on stimulation by hydraulic fracturing. Traditional hydraulic fracturing practices, however, are in many ways inadequate in addressing difficulties associated with these non-conventional and conventional resources. For example, complex in-situ stress distribution, large material property contrasts and unique production mechanism complicate the implementation of hydraulic fracture treatments in CBM and gas-condensate reservoirs respectively. An integrated approach to optimise hydraulic fracture treatments in reservoirs under complex conditions is developed in this thesis. The optimisation methodology integrates a fracture geometry model which predicts fracture geometry for a given set of treatment parameters, a production model which estimates reservoir productivity after stimulation and an economic model which calculates net present value. A stochastic optimisation algorithm combining features of evolutionary computations is used to search for the optimum design. Numerical techniques such as finite element analysis, iterative semi-analytical methods and evolutionary computation are also used. The following are the major contributions of this thesis: 1. A three-dimensional hydraulic fracture geometry model which accounts for poroelastic effects, in-situ stress and rock material properties, has been developed to provide a more realistic description of the hydraulic fracture geometry. This served as a tool to visualise hydraulic fracture propagation for a given in-situ stress distribution, rock material properties and treatment parameters. Furthermore, by accounting for poroelastic effects, it is possible to identify the causes of exceptionally high treatment pressures. 2. An innovative production model was formulated in this thesis to quantify the well deliverability due to hydraulic fracturing. The production model has been used for a range of production scenarios for CBM and gas-condensate reservoirs such as: multiple wells at arbitrary locations and various well types (stimulated and unstimulated wells). 3. The optimisation methodology presented in this work provides a platform for operators to assess risks and gains associated with different field development scenarios. The added feature of sub-optimal NPV contouring provided flexibility to calibrate the treatment design in real-time. The strength of the optimisation methodology lies in the flexibility to: (1) impose design constraints, (2) optimise multiple variables and (3) simulate multiple objectives.
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Echavarria, Erika. "Acoustic properties of a 2-D fracture during formation." Morgantown, W. Va. : [West Virginia University Libraries], 1999. http://etd.wvu.edu/templates/showETD.cfm?recnum=1143.

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Thesis (M.S.)--West Virginia University, 1999.
Title from document title page. Document formatted into pages; contains xiii, 132 p. : ill. (some col.) Includes abstract. Includes bibliographical references (p. 98).
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VELOZO, LILIANE TOJEIRA. "STUDY OF PROPPED MATERIAL OF FRACTURES STIMULATED BY HYDRAULIC FRACTURING IN OIL WELLS." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2006. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=8725@1.

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CONSELHO NACIONAL DE DESENVOLVIMENTO CIENTÍFICO E TECNOLÓGICO
A viabilidade da exploração de um campo petrolífero está associada às características produtivas da formação, obtidas mediante o desenvolvimento e a aplicação de técnicas capazes de aumentar a economicidade dos poços. A técnica de estimulação mais utilizada atualmente é o fraturamento hidráulico, que tem como uma das etapas principais a injeção de um material granular, denominado de propante, para a manutenção da abertura da fratura. Tal técnica tem como obstáculo o refluxo do propante para o interior do poço (proppant flowback), ocasionando diversos problemas que podem levar à interrupção da produção do mesmo. Alguns modelos teóricos e empíricos foram desenvolvidos para a previsão desse fenômeno, mas os mecanismos que o governam não são ainda claramente explicados. Alguns fatores que influenciam na produção de propante são largura da fratura, tensão de fechamento, gradiente hidráulico e características do propante. O refluxo de propante não é considerado nos procedimentos atuais de projeto de fraturamento hidráulico. Nessa dissertação de mestrado foi desenvolvida uma ferramenta computacional com uma arquitetura orientada a objeto, em linguagem de programação Java, para a análise de estabilidade do propante no interior da fratura com base em modelos empíricos e teóricos. Além disso, foi investigada a influência da inclusão de restrições no projeto de fraturamento de modo a prevenir o fenômeno. Busca-se, desse modo, a obtenção de melhores projetos de fraturamento hidráulicos com prevenção do refluxo de propante, garantindo a produtividade do poço e prolongando sua vida útil.
The viability of the exploration of an oil field is associated with the productive characteristics of the formation, guaranteed by means of the development and application of techniques capable of increasing the productivity and the economy of the oil fields. The currently most used stimulation technique is hydraulic fracturing, by which one of the main stages is the injection of a granular material called proppant to keep the fracture open and enhance fracture permeability. This technique presents as a drawback the phenomenon known as proppant flowback. The proppant is carried to the inside of the well causing many problems which can lead to production interruption. Some empirical and theoretical models for its prediction have been developed, however the mechanisms that govern it are still not clearly explained. Parameters that are related to proppant flowback are fracture width, closure pressure, drag force and proppant characteristics. Proppant flowback prediction is not included in today s procedures of the hydraulic fracturing project. In the present work a computational tool for proppant stability analysis was developed based on empirical and theoretical prediction models. This tool has an object oriented architecture written in Java language. The influence of the introduction of restrictions to prevent proppant production in the hydraulic fracture design procedure was also investigated. In this way, it is aimed to obtain hydraulic fracturing projects by which proppant flowback is prevented in field situations assuring well productivity and extending its activity period.
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Yin, Qingqing. "Transporting and Disposing of Wastewater from North Dakota Oil Producers." Thesis, North Dakota State University, 2012. https://hdl.handle.net/10365/26541.

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North Dakota?s oil boom is aided by a new technology, fracking. But this technology implies large amounts of wastewater. The methods of dealing with this wastewater are now an issue. Currently, North Dakota locks it into deep injection wells in the Bakken formation. With the development of membrane technologies to treat wastewater, it may be feasible to treat the wastewater and reuse it. This study uses a mathematical programming model to minimize the total cost of dealing with wastewater using three methods - deep well injection, on-site treatment, and off-site treatment. The model results show it is cost-effective to use on-site and large capacity off-site treatment to treat the 20% of the wastewater that flows back within the first 30-60 days after a well is drilled.
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Dohde, Farhan A. "Estimation of Air Emissions During Production Phase from Active Oil and Gas Wells in the Barnett Shale Basin: 2010-2013." Thesis, University of North Texas, 2015. https://digital.library.unt.edu/ark:/67531/metadc799523/.

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The Barnett shale basin, the largest onshore gas field in the state of Texas, mainly produces natural gas. The basin’s oil and gas productions have dramatically increased over the past two decades with the enhancement via shale fracturing (fracking) technology. However, recent studies suggest that air emissions from shale fracking have significantly contributed to the growing air pollution problem in North Texas. In this study, air emissions from the Barnett shale basin during the production phase of the oil and gas activities (once the product is collected from the wells) are quantified. Oil and gas production data were acquired from the Texas Railroad Commission for the baseline years of 2010 through 2013. Methodology from prior studies on shale basins approved by the Texas Commission on Environmental Quality was employed in this study and the emission inventories from the production phase sources were quantified. Accordingly, the counties with the most gas operations in the basin, Tarrant, Johnson, Denton and Wise, were found to be the highest emitters of air pollutants. Tarrant County was responsible for the highest emitted NOx (42,566 tons) and CO (17,698 tons) in the basin, while Montague County released the maximum VOC emissions (87,601 tons) during the study period. Amongst the concerned emitted pollutants, VOC was the largest emitted pollutant during the study period (417,804 tons), followed by NOx (126,691 tons) and CO (47,884 tons). Significant Sources of air emissions include: storage tanks, wellhead compressor engines, and pneumatic devices. Storage tanks and pneumatic devices contributed to about 62% and 28% of the total VOC emissions, respectively. Whereas, wellhead compressor engines are primarily responsible for about 97% of the total NOx emissions. Finally, in Tarrant, Wise and Denton counties, the emissions increased during the study period due to increase in the oil and gas production, while Johnson County’s emission contribution declined throughout the study period.
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Neumann, Luís Fernando. "Investigação experimental sobre a geração, visualização e avaliação da condutividade de fraturas ácidas em carbonatos microbiais." [s.n.], 2011. http://repositorio.unicamp.br/jspui/handle/REPOSIP/265384.

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Orientadores: Jose Luiz Antunes de Oliveira e Sousa, Paulo Dore Fernandes
Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências
Made available in DSpace on 2018-08-18T16:09:28Z (GMT). No. of bitstreams: 1 Neumann_LuisFernando_M.pdf: 28066529 bytes, checksum: 854d0f8d8feee96cc1c3e1adff5373dc (MD5) Previous issue date: 2011
Resumo: O sucesso da estimulação por fraturamento hidráulico ou ácido é dependente da geração de condutividade. No fraturamento hidráulico sustentado, a condutividade é gerada pela introdução de uma quantidade significativa de um agente de sustentação granular e praticamente esférico. No fraturamento ácido, a condutividade é gerada por irregularidades reveladas devido à reação desigual do ácido em cada uma das faces da fratura naturalmente rugosa e da resistência destas mesmas irregularidades para suportar as tensões que atuam após o fechamento da fratura. A baixa resistência das irregularidades leva ao colapso e cicatrização da fratura ácida com a perda total da condutividade. Esta dissertação investiga a viabilidade da estimulação por fraturamento ácido em carbonatos microbiais rasos e profundos. Ensaios de laboratório em escala reduzida foram projetados para verificar se a condutividade de uma fratura induzida por reação química da rocha reservatório com um ácido forte pode ser mantida frente às elevadas tensões normais efetivas que agirão na fase de explotação do poço. A dissertação ainda investiga se o emprego de uma pequena quantidade de agente de sustentação é capaz de dividir os esforços aplicados sobre as irregularidades de uma fratura ácida e manter a condutividade por maiores períodos de tempo. As superfícies que imitam fraturas ácidas são criadas pelo ataque ácido em corpos de prova em condições de laboratório que reproduzem em escala aquelas observadas em um fraturamento ácido real. Imagens digitais são utilizadas para medir a rugosidade das fraturas ácidas e o consumo de rocha carbonática pelo ácido na face do corpo de prova. A resistência das irregularidades é medida indiretamente pelo decréscimo da condutividade da fratura ácida frente a tensões de confinamento crescentes. O efeito ou não da adição de agente de sustentação é medido pela comparação dos parâmetros da correlação empírica desenvolvida por Nierode e Kruk
Abstract: A well succeeded stimulation by hydraulic or acid fracturing is related to conductivity creation. In a hydraulic fracturing, the conductivity is created by means of introducing a significant amount of a propping agent. In an acid fracturing, the conductivity is related to the creation of asperities due to uneven acid reaction on each naturally rougher fracture side and the asperities strength to withstand high stresses that start to act just after fracture closure. Low asperities strength leads to collapse of acid fracture and fracture healing with total conductivity loss. The dissertation investigates the feasibility of acid fracturing stimulation in shallow and deep microbial carbonates. Laboratory tests were designed to verify if the acid fracture conductivity induced by chemical reaction of reservoir rock with a strong acid could be kept when facing the high effective normal stress that is expected in exploitation phase. The dissertation still investigates whether the use of a small amount of proppant is able to share the tension that acts on asperities and maintain the acid facture conductivity for longer periods. The surfaces that mimic acid fractures are created by acid etching specimens in laboratory conditions reduced in scale from those observed in an actual acid fracturing job. Digital images are used to measure fracture roughness and rock consumption by acid on the specimen face. The asperities strength is indirectly measured from acid conductivity decrease under increased confinement tension. The effect of adding or not adding propping agent is accomplished comparing empirical parameters from Nierode and Kruk correlation
Mestrado
Explotação
Mestre em Ciências e Engenharia de Petróleo
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Cleto, Pedro Rogério. "Simulação de fraturamento hidráulico usando elementos finitos de elevada razão de aspecto com acoplamento hidromecânico /." Bauru, 2016. http://hdl.handle.net/11449/140148.

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Orientador: Osvaldo Luís Manzoli
Banca: Flavia de Oliveira Lima Falcão
Banca: Leonardo José do Nascimento Guimarães
Resumo: A técnica de fraturamento hidráulico é amplamente utilizada na indústria petrolífera para aumentar a permeabilidade da rocha-reservatório numa região próxima ao poço e permitir a extração, e consequente produção, de hidrocarbonetos armazenados em seus poros. Primeiramente a rocha é perfurada criando-se um poço e então injeta-se fluido a uma pressão suficientemente alta para fraturar a rocha. A injeção contínua de fluido permite que as fraturas se propaguem pelo reservatório, formando assim canais de alta permeabilidade. A modelagem e simulação computacional de fraturamento hidráulico são complexas em função da física envolvida no processo. O presente trabalho objetiva o estudo da formação e propagação de fraturas induzidas hidraulicamente em meios rochosos de baixa permeabilidade e também tem o propósito de verificar se a metodologia adotada é capaz de reproduzir características apresentadas num processo de fraturamento hidráulico, como a pressão necessária para causar a ruptura da rocha. Para tal, apresenta-se a técnica de fragmentação da malha utilizando elementos finitos de elevada razão de aspecto (ou elementos de interface) para representar a fratura, aos quais são atribuídas relações constitutivas baseadas na mecânica do dano. Além disso, os elementos de interface também possuem um acoplamento hidromecânico capaz de representar o canal de alta permeabilidade devido à ocorrência da fratura. Os resultados obtidos mostraram que os elementos de interface asso... (Resumo completo, clicar acesso eletrônico abaixo)
Abstract: The hydraulic fracturing technique is widely used to increase the permeability of reservoirs in the vicinity of the well and to allow the extraction and subsequent production of hydrocarbons trapped in its pores. Firstly, the rock is drilled, creating a well and then a fluid is injected at a sufficiently high pressure to fracture the rock. The continuous fluid injection allows the fractures to propagate through the reservoir, thereby forming some high permeability paths. The computer modeling and simulation of hydraulic fracturing are complex due to the physics involved in the process. This work aims to study the formation and propagation of hydraulically induced fractures in rocky media with low permeability and also aims to verify if the adopted methodology is able to reproduce the characteristics presented in a hydraulic fracturing process, as for instance, the required pressure to cause the breakdown of the rock. For this purpose, it is presented the mesh fragmentation technique using finite elements with a high aspect ratio (or interface elements) to represent the fracture, which are assigned constitutive relations based on damage mechanics. Besides, the interface elements also have a hydromechanical coupling which is able to represent the high permeability path due to the fracture. The results showed that the interface elements associated with the mesh fragmentation technique were able to represent both the formation and the propagation of hydraulically induc... (Complete abstract click electronic access below)
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Damas, Renato Gomes. "Avaliação da qualidade dos modelos de fraturamento hidraulico." [s.n.], 2005. http://repositorio.unicamp.br/jspui/handle/REPOSIP/258703.

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Abstract:
Orientadores: Philippe Remy Bernard Devloo, Sonia Maria Gomes
Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Civil, Arquitetura e Urbanismo
Made available in DSpace on 2018-08-14T02:00:38Z (GMT). No. of bitstreams: 1 Damas_RenatoGomes_M.pdf: 3286162 bytes, checksum: 85d0d261382f505e55d4f5544f378238 (MD5) Previous issue date: 2005
Resumo: Neste trabalho avalia-se três modelos que retratam o processo de fraturamento hidráulico. O primeiro, desenvolvido por Fernandes [1998], trata-se de um modelo semi- nalítico cuja formulação fundamenta-se na taxa constante de injeção de fluido fraturante. Esse modelo apresenta como vantagem a simplicidade dos cálculos e a obtenção imediata dos resultados, por outro lado tem seu campo de atuação limitado a intervalos específicos de eficiência volumétrica para os quais foi elaborado. Os outros dois são modelos numéricos desenvolvidos por Devloo et al. [2001] e Devloo [2001]. Incorporam em seu equacionamento taxa variável de injeção e por efetuarem cálculos iterativos são independentes quanto a eficiência volumétrica do processo. Os resultados dos modelos numéricos foram comparados com os do modelo semi-analítico. Buscando-se, desta forma, validar os modelos numéricos para o uso em simulações de fraturamento hidráulico, principalmente para as condições de injeção de água presentes em poços com alta porosidade. Pretende-se com isso oferecer maior liberdade e flexibilidade durante o planejamento da operação de fraturamento. Oferecendo ao projetista a possibilidade de adoção de taxa injeção variável, períodos sem injeção intercalados com períodos com injeção, liberdade para utilização de diferentes fluidos fraturantes entre outros benefícios.
Abstract: The purpose of this research has been evaluated three models of hidraulic fracturing. The first one, developed byFernandes [1998], is a semi-analytical model whose formulation is based on a constant rate of injection of fracturing fluid. This model presents as advantage the simplicity of the calculations and the immediate attainment of the results, on the other hand its performance is limited at specific intervals of volumetric efficiency for which it was elaborated. The others two are numerical models developed by Devloo et al. [2001] and Devloo [2001]. They incorporate variable injection rate and due to the iterative calculations they are not limited in a range of volumetric efficiency of the process. The results of the numerical models had been compared with the ones of the semianalytical model. Searching, in such a way, to validate the numerical models for the use in simulation of hydraulic fracturing, mainly for the characteristic conditions of water injection present in wells with high porosity. It is intended with this to provide freedom and flexibility during the planning of the operation of fracturing. Offering to the designer the possibility to use variable injection rate, periods without injection intercalated with periods with injection, freedom to choose differents fracturing fluids among others benefits.
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Books on the topic "Oil wells – Hydraulic fracturing"

1

Handbook of hydraulic fracturing. Hoboken, New Jersey: John Wiley & Sons, Inc., 2016.

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Yew, Ching H. Mechanics of hydraulic fracturing. Houston, Tex: Gulf Pub. Co., 1997.

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Mader, Detlef. Hydraulic proppant fracturing and gravel packing. Amsterdam: Elsevier, 1989.

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Valkó, Peter. Hydraulic fracture mechanics. Chichester: Wiley, 1995.

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K, Britt Larry, ed. Design and appraisal of hydraulic fractures. Richardson, TX: Society of Petroleum Engineers, 2009.

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Jones, Jack R. Design and appraisal of hydraulic fractures. Richardson, TX: Society of Petroleum Engineers, 2009.

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Mikhali͡uk, Alʹfred Vladimirovich. Impulʹsnyĭ razryv porod. Kiev: Nauk. dumka, 1991.

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Weijers, Leendert. The near-wellbore geometry of hydraulic fractures initiated from horizontal and deviated wells. Delft, The Netherlands: Delft University Press, 1995.

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Hydraulic fracturing and natural gas drilling: Questions and concerns. Hauppauge, N.Y: Nova Science Publishers, 2011.

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J, Economides Michael, ed. Hydraulic fracture mechanics. Chichester: Wiley, 1995.

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Book chapters on the topic "Oil wells – Hydraulic fracturing"

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Chen, Fei, Zu-wen Wang, and Yan-ping Zhang. "Research and Application of Hydraulic Pumping Bridge Plug Fracturing Technology in Oil Wells." In Springer Series in Geomechanics and Geoengineering, 2496–501. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-2485-1_228.

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Salavatov, T. Sh, and Khurram Iqbal. "Application of Fuzzy Logic in Selection of Best Well for Hydraulic Fracturing in Oil and Gas Fields." In Advances in Intelligent Systems and Computing, 413–19. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-35249-3_53.

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Reible, Danny D., Soraya Honarparvar, Chau-Chyun Chen, Tissa H. Illangasekare, and Margaret MacDonell. "Environmental Impacts of Hydraulic Fracturing." In Environmental Technology in the Oil Industry, 199–219. Cham: Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-24334-4_6.

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Romagnoli, R., and R. Varvelli. "Statistical Approach to the Computer Modelling of Hydraulic Fracturing in Hydrocarbon Reservoirs." In North Sea Oil and Gas Reservoirs—II, 223–27. Dordrecht: Springer Netherlands, 1990. http://dx.doi.org/10.1007/978-94-009-0791-1_18.

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Jianhua, Xu, Nadir Husein, Kirill Ovchinnikov, Anton Buyanov, Ruslan Gazizov, Anna Belova, Zhao Yuxin, Cui Bin, and Zhang Qunshuang. "Using Markers for Production Logging in Horizontal Gas Wells with Multistage Hydraulic Fracturing." In Proceedings of the International Petroleum and Petrochemical Technology Conference 2020, 456–66. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-16-1123-0_43.

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Villalobos-Hiriart, Alejandro, Amado Enrique Navarro-Frómeta, Pablo Arturo Gómez-Durán, Walfrido Alonso-Pippo, María del Carmen Durán-Domínguez-de-Bazúa, and Alberta Maura Jiménez-Vásquez. "Implications of Hydraulic Fracturing of Unconventional Oil and Gas Resources in Mexico." In Water Availability and Management in Mexico, 99–123. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-24962-5_5.

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Zhang, He-wen, Xue-mei Yan, Hong-ge Jia, Jun Yan, Yu-ping Sun, and Hai-bo Li. "Effective Development of Old Wells Residual Oil by Degradable Fiber Diverting Acid-Fracturing Technology." In Springer Series in Geomechanics and Geoengineering, 2514–21. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-2485-1_230.

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Nguyen, Huu Truong, and Van Hung Nguyen. "Lesson Learned from Hydraulic Fracturing Stimulation for Improved Oil Production Rate in the Lower Miocene Reservoir, Offshore Viet Nam." In Lecture Notes in Civil Engineering, 559–65. Singapore: Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-13-2306-5_79.

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Briskin, J. S., and L. Yohannes. "Overview of U.S. EPA’s Study of the Potential Impacts of Hydraulic Fracturing for Oil and Gas on Drinking Water Resources." In ACS Symposium Series, 197–203. Washington, DC: American Chemical Society, 2015. http://dx.doi.org/10.1021/bk-2015-1216.ch009.

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Xie, Gui-qi, Hai Lin, You-yu Wan, Youg-xia Pu, Xin-yuan Feng, Shi-duo Liu, and Yong Liu. "Study on Optimal Volumetric Fracturing Design of Horizontal Tight Oil Wells in $$ {\mathbf{E}}_{3}^{2} $$ Pre-salt Reservoir in Yingxi Area, Qaidam Basin." In Springer Series in Geomechanics and Geoengineering, 938–54. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-16-0761-5_89.

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Conference papers on the topic "Oil wells – Hydraulic fracturing"

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Wang, Yan, Demin Wang, Zhi Sun, Changlan Shi, Gang Wang, and Desheng Li. "Hydraulic Fracturing of Polymer Injection Wells." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2004. http://dx.doi.org/10.2118/88592-ms.

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Wenjun, Wang, Wang Lin, Xingfu Zhang, Qingyou Sun, Pengfei Tang, Wang Haitao, Zhongsheng Wu, and Qingtiao Zhang. "Hydraulic Fracturing in Low Temperature Horizontal Wells." In SPE Oil and Gas India Conference and Exhibition. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/127266-ms.

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Catlett, Richard D., Jon D. Spencer, Elyezer Lolon, and Dave Bucior. "Evaluation of Two Horizontal Wells in the Eagle Ford Using Oil-Based Chemical Tracer Technology to Optimize Stimulation Design." In SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2013. http://dx.doi.org/10.2118/163846-ms.

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Aslanyan, Arthur, Irina Aslanyan, Roman Kuzyutin, Maxim Volkov, Radhakrishnan Karantharath, and Fathi Shnaib. "Characterising Hydraulic Fracture Contribution in Shale Oil Wells Using High-Precision Temperature and Spectral Noise Logging." In SPE Asia Pacific Hydraulic Fracturing Conference. Society of Petroleum Engineers, 2016. http://dx.doi.org/10.2118/181792-ms.

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Aitov, Ch R. "Well Clustering for The Subsequent Identification of Candidate Wells for Hydraulic Fracturing." In Data Science in Oil and Gas 2021. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.202156017.

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Kovalenko, Igor Victorovich. "Well Test Analysis of Horizontal Wells and Vertical Wells with Hydraulic Fracturing Applied in Heavy Oil Fields." In SPE Heavy Oil Conference Canada. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/156936-ms.

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Yang, Fen, Larry K. Britt, and Shari Dunn-Norman. "The Effect of Well Azimuth or Don't Let Your Landman Plan Your Well Path!" In SPE Hydraulic Fracturing Technology Conference. SPE, 2015. http://dx.doi.org/10.2118/spe-173331-ms.

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Abstract Since the late 1980's when Maersk published their work on multiple fracturing of horizontal wells in the Dan Field, the use of transverse multiple fractured horizontal wells has become the completion of choice and become the “industry standard” for unconventional and tight oil and tight gas reservoirs. Today approximately sixty percent of all wells drilled in the United States are drilled horizontally and nearly all of them are multiple fractured. Because a horizontal well adds additional cost and complexity to the drilling, completion, and stimulation of the well we need to fully understand anything that affects the cost and complexity. In other words, we need to understand the affects of the principal stresses, both direction and magnitude, on the drilling completion, and stimulation of these wells. However, little work has been done to address and understand the relationship between the principal stresses and the lateral direction. This paper has as its goal to fundamentally address the question, in what direction should I drill my lateral? Do I drill it in the direction of the maximum horizontal stress (longitudinal) or do I drill it in the direction of the minimum horizontal stress (transverse)? The answer to this question relates directly back to the title of this paper and please "Don't let your land man drive that decision." This paper focuses on the horizontal well's lateral direction (longitudinal or transverse fracture orientation) and how that direction influences productivity, reserves, and economics of horizontal wells. Optimization studies using a single phase fully three dimensional numeric simulator including convergent non-Darcy flow were used to highlight the importance of lateral direction as a function of reservoir permeability. These studies, conducted for both oil and gas, are used to identify the point on the permeability continuum where longitudinal wells outperform transverse wells. The simulations compare and contrast the transverse multiple fractured horizontal well to longitudinal wells based on the number of fractures and stages. Further, the effects of lateral length, fracture half-length, and fracture conductivity were investigated to see how these parameters affected the decision over lateral direction in both oil and gas reservoirs. Additionally, how does completion style affect the lateral direction? That is, how does an open hole completion compare to a cased hole completion and should the type of completion affect the decision on in what direction the lateral should be drilled? These simulation results will be used to discuss the various horizontal well completion and stimulation metrics (rate, recovery, and economics) and how the choice of metrics affects the choice of lateral direction. This paper will also show a series of field case studies to illustrate actual field comparisons in both oil and gas reservoirs of longitudinal versus transverse horizontal wells and tie these field examples and results to the numeric simulation study. This work benefits the petroleum industry by: Establishing well performance and economic based criteria as a function of permeability for drilling longitudinal or transverse horizontal wells,Integrating the reservoir objectives and geomechanic limitations into a horizontal well completion and stimulation strategy,Developing well performance and economic objectives for horizontal well direction (transverse versus longitudinal) and highlighting the incremental benefits of various completion and stimulation strategies.
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Hall, K., A. Dahi Taleghani, and N. Dahi Taleghani. "On Liability Issues Concerning Induced Seismicity in Hydraulic Fracturing Treatments and at Injection Disposal Wells: What Petroleum Engineers should know." In SPE Hydraulic Fracturing Technology Conference. SPE, 2015. http://dx.doi.org/10.2118/spe-173383-ms.

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Abstract The rates of oil and natural gas production in the United States have increased dramatically during the past decade, largely due to the use of hydraulic fracturing and horizontal drilling. This has benefitted the U.S. economy and generated hopes that the “shale revolution” could be replicated elsewhere. At the same time, however, public concern has grown regarding potential adverse impacts that fracing or other operations like gas flooding, waterflooding, waste disposal, and other production processes may have. One of the main public concerns relates to induced seismic events – that is, man-made earthquakes. Geologists have concluded that a variety of human activities can induce seismic events. Such operations include the operation of injection disposal wells, though a relatively small fraction of such wells are suspected of inducing seismic activity. Further, available public data shows that, on very rare occasions, hydraulic fracturing itself has caused tangible seismic activity. Although such events have been uncommon, they have attracted significant public attention and strengthened the opponents of oil and gas development. Further, although seismic events induced by oil and gas activity appear to have caused little damage, the potential legal liability could be substantial if such an event ever caused significant damage. Accordingly, industry should give increased attention to minimizing the likelihood of such events. The paper provides context for this issue by briefly reviewing information regarding recent cases of induced seismic activity, current technology for monitoring these events, and the inherent limitations in measurements and interpretation involved in using these techniques. This paper also discusses techniques that operators can use to reduce the likelihood of induced seismic events at hydraulic fracturing sites and at injection disposal wells. These include use of pretreatment geomechanical analyses to assess the likelihood of significant seismic events and, in appropriate circumstances, to guide a modification in perforation clusters design to reduce the likelihood of nearby fault reactivations. Finally, the article provides additional context by discussing relevant laws, including regulatory responses to suspected events of induced seismic activity and the possible legal theories for imposing liability for such events. The new regulations will compel operators to take certain actions and the potential for legal liability may incentivize additional action.
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Nejad, Amir M., Stanislav Sheludko, Robert F. Shelley, Trey Hodgson, and Riley McFall. "A Case History: Evaluating Well Completions in the Eagle Ford Shale Using a Data-Driven Approach." In SPE Hydraulic Fracturing Technology Conference. SPE, 2015. http://dx.doi.org/10.2118/spe-173336-ms.

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AbstractUnconventional shale resources are key hydrocarbon sources, gaining importance and popularity as hydrocarbon reservoirs both in the United States and internationally. Horizontal wellbores and multiple transverse hydraulic fracturing are instrumental factors for economical production from shale assets. Hydraulic fracturing typically represents a major component of total well completion costs, and many efforts have been made to study and investigate different strategies to improve well production and reduce costs. The focus of this paper is completion effectiveness evaluation in different parts of the Eagle Ford Shale Formation, and our objective is to identify appropriate completion strategies in the field.A data-driven neural network model is trained on the database comprised of multiple operators' well data. In this model, drilling and mud data are used as indicators for geology and reservoir-related parameters such as pressure, fluid saturation and permeability. Additionally, completion- and fracture-related parameters are also used as model inputs. Because wells are pressure managed differently, normalized oil and gas production is used as a model output. Thousands of neural networks are trained using genetic algorithm in order to fully evaluate hidden correlations within the database. This results in selection of a neural network that is able to understand reservoir, completion and frac differences between wells and identify how to improve future completion/stimulation designs.The final neural network model is successfully developed and tested on two separate data sets located in different parts of the Eagle Ford Shale oil window. Further, an additional test data set comprised of eight wells from a third field location is used to validate the predictive usefulness of the data-driven model. Under-producing wells were also identified by the model and new fracture designs were recommended to improve well productivity.This paper will be useful for understanding the effects of completion and fracture treatment designs on well productivity in the Eagle Ford. This information will help operators select more effective treatment designs, which can reduce operational costs associated with completion/fracturing and can improve oil and gas production.
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Malhotra, Sahil, Tom Merrifield, Cynthia Lynch, Dave Larue, Angela Madding, and Jye Collins. "Coiled Tubing Horizontal Well Fracturing in the Low Young's Modulus, Low Permeability Belridge Diatomite: Challenges Faced and Lessons Learned." In SPE Hydraulic Fracturing Technology Conference. SPE, 2015. http://dx.doi.org/10.2118/spe-173365-ms.

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Abstract Coiled tubing fracturing has been successfully applied in multi-stage vertical well stimulation in the Belridge diatomite in the Lost Hills field. This same methodology was used to complete two northwest-trending horizontal wells drilled on the northeast flank of the Lost Hills anticlinal structure that targeted thinner higher oil-saturation strata, separated by thicker low oil-saturation intervals. The target reservoir is comprised of high porosity, low matrix permeability Opal A diatomite. The perforations were jetted by pumping sand slurry down the coiled tubing and the frac job was pumped down the annulus. The stages were isolated by setting sand plugs. Nine and twelve stages were pumped in the two wells respectively. The perforation locations for different stages were selected in areas with: 1) high resistivity and inferred high oil saturations, 2) absence of hydraulic fractures from nearby wells, 3) excellent cement bonding, and 4) low intensity of natural fractures. These assessments followed logging while drilling (LWD) gamma ray, induction resistivity and azimuthally focused resistivity (image) logs and cased-hole ultrasonic image tool (USIT) run with the aid of a tractor. The hydraulic fractures were monitored using surface tiltmeter sensors. Oil and water soluble tracers were pumped to determine the relative production contribution from the stages and fracture fluid cleanup, respectively, from the stages. All the jobs could be successfully pumped without any screen outs. Challenges were faced in setting sand plugs and isolating stages. Large fracture widths and low leak-off into the formation led to difficulty in forming sand bridges at the perforations and concentrating sand in the wellbore for the plugs. Surface tiltmeters showed excessive fracture height growth. Tracer results showed that 20-30% of the stages contributed to 50-60% of the production. Stages with higher treating pressures contributed less towards production. This could be attributed to near wellbore tortuosity in these stages. Proppant flowback was encountered in one well, and after an effective clean up the production rose. The study illustrates how integration of various aspects such as completion design, fracture pressure analysis and diagnostics combined with geologic and reservoir information can help in identifying challenges and finding potential solutions of hydraulic fracturing. The findings highlight that the technology most suitable for vertical well stimulation might not be favorable for horizontal well stimulation.
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Reports on the topic "Oil wells – Hydraulic fracturing"

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Laue, M. L. Economic Recovery of Oil Trapped at Fan Margins Using Hig Angle Wells Multiple Hydraulic Fractures. Office of Scientific and Technical Information (OSTI), November 1997. http://dx.doi.org/10.2172/328513.

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Mike L. Laue. Economic Recovery of Oil Trapped at Fan Margins Using High Angle Wells Multiple Hydraulic Fractures. Office of Scientific and Technical Information (OSTI), October 1997. http://dx.doi.org/10.2172/1562.

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Mike L. Laue. ECONOMIC RECOVERY OF OIL TRAPPED AT FAN MARGINS USING HIGH ANGLE WELLS AND MULTIPLE HYDRAULIC FRACTURES. Office of Scientific and Technical Information (OSTI), September 2001. http://dx.doi.org/10.2172/811814.

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Laue, M. L. Economic Recovery of Oil Trapped at Fan Margins Using High Angle Wells and Multiple Hydraulic Fractures. Office of Scientific and Technical Information (OSTI), November 1999. http://dx.doi.org/10.2172/14233.

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Laue, M. L. Economic Recovery of Oil Trapped at Fan Margins Using High Angle Wells and Multiple Hydraulic fractures. Office of Scientific and Technical Information (OSTI), August 1997. http://dx.doi.org/10.2172/643508.

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Mike L. Laue. Economic Recovery of Oil Trapped at Fan Margins Using High Angle Wells and Multiple Hydraulic Fractures. Office of Scientific and Technical Information (OSTI), May 1997. http://dx.doi.org/10.2172/2206.

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Mike L. Laue. Economic Recovery of Oil Trapped at Fan Margins Using High Angle Wells and Multiple Hydraulic Fractures. Office of Scientific and Technical Information (OSTI), February 1998. http://dx.doi.org/10.2172/1563.

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Mike L. Laue. Economic Recovery of Oil Trapped at Fan Margins Using High Angle Wells and Multiple Hydraulic Fractures. Office of Scientific and Technical Information (OSTI), May 1998. http://dx.doi.org/10.2172/1564.

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Mike L. Laue. Economic Recovery of Oil Trapped at Fan Margins Using High Angle Wells and Multiple Hydraulic Fractures. Office of Scientific and Technical Information (OSTI), May 1997. http://dx.doi.org/10.2172/1561.

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Mike L. Laue. ECONOMIC RECOVERY OF OIL TRAPPED AT FAN MARGINS USING HIGH ANGLE WELLS AND MULTIPLE HYDRAULIC FRACTURES. Office of Scientific and Technical Information (OSTI), November 1998. http://dx.doi.org/10.2172/818571.

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