Analysis on the Impact of Fracturing Treatment Des.docx
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1、IPTC 16400Analysis on the Impact of Fracturing Treatment Design and ReservoirProperties on Production from Shale Gas ReservoirsC.E. Cohen, C. Abad, X. Weng, K. England, A. Phatak, O. Kresse, O. Nevvonen, V. Lafitte, P. Abivin,SchlumbergerCopyright 2013, International Petroleum Technology ConferenceT
2、his paper was prepared for presentation at the International Petroleum Technology Conference held in Beijing, China, 2628 March 2013.This paper was selected for presentation by an IPTC Programme Committee following review of information contained in an abstract submitted by the author(s). Contents o
3、f the paper, aspresented, have not been reviewed by the International Petroleum Technology Conference and are subject to correction by the author(s). The material, as presented, does not necessarilyreflect any position of the International Petroleum Technology Conference, its officers, or members. P
4、apers presented at IPTC are subject to publication review by Sponsor SocietyCommittees of IPTC. Electronic reproduction, distribution, or storage of any part of this paper for commercial purposes without the written consent of the International Petroleum TechnologyConference is prohibited. Permissio
5、n to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuousacknowledgment of where and by whom the paper was presented. Write Librarian, IPTC, P.O. Box 833836, Richardson, TX 75083-3836, U.S.A., fax +1-972-95
6、2-9435AbstractProduction from shale gas reservoirs depends greatly on the efficiency of hydraulic fracturing treatments. The cumulatedexperience in the industry has led to several best practices in treatment design, which have improved productivity of thesereservoirs. However, further advancement of
7、 treatment design requires a deeper understanding of the complex physicsinvolved in both hydraulic fracturing and production, such as stress shadow, proppant placement and treatment interactionwith pre-existing natural fractures.This paper sheds light on the non-linear physics involved in the produc
8、tion of shale gas reservoirs by improving theunderstanding of the complex relation between gas production, the reservoir properties, and several treatment designparameters. A fracturing-to-production simulation workflow integrating the Unconventional Fracture Model (Weng et al.,2011), with the Uncon
9、ventional Production Model (Cohen et al., 2012) is presented. By applying this workflow to a realisticreservoir, we did an extensive parametric study to investigate the relation between production and treatment designparameters such as fracturing fluid viscosity, proppant size, proppant concentratio
10、n, proppant injection order, treatmentvolume, pumping rate, pad size and hybrid treatment. The paper also evaluates the influence of unconventional reservoirproperties - such as permeability, horizontal stress, horizontal stress anisotropy, horizontal stress orientation, Poissons ratioand Youngs mod
11、ulus on production. Since this paper focuses on fluid and proppant selection, our methodology was to run28 simulations to cover the 2D parametric space of proppant size and fracturing fluid viscosity for all of these parameters.More than fourteen hundred simulations were run in this parametric study
12、 and the results provide guidelines for optimizedtreatment design.This paper illustrates how this unique workflow can identifies the optimum fluid and proppant selection that gives themaximum production for a given reservoir and completion. In addition, the parametric study shows how these optimumse
13、volve as a function of reservoir and treatment parameters. The results validate several best practices in treatment design forshale. For example, combination of different sizes of proppant optimizes production by maximizing initial production andslowing down production decline. Simulations also conf
14、irm the best practice of injecting the smallest proppant first. Thestudy explains why slickwater treatments should be injected at maximum pumping rate and preferably with 40/70 mesh sand.It also illustrates why reservoirs with high Youngs modulus (such as the Barnett shale) can be stimulated effecti
15、vely withslickwater. Another key finding is that the optimum fluid viscosity increases with treatment volume.IntroductionThe production from shale gas reservoirs depends greatly on the efficiency of the stimulation, more than for conventionalreservoirs. The cumulated experience in our industry on th
16、e technique of hydraulic fracturing has led to best practices intreatment design that have contributed to the fast increase in productivity of shale gas wells over the last decade (Kennedy,2012). This knowledge has been built from trial and error over time and numerous wells, but it is a difficult p
17、ath challengedby the great uncertainties and variations in reservoir properties from basin to basin, even from well to well. The early days ofshale fracturing succeeded in the Barnett play with slickwater and relatively small proppant (80/100 mesh, 40/70 mesh) tocreate economically sound wells (Coul
18、ter et al., 2004, Baihly et al., 2010). Nevertheless the development of shale plays2IPTC 16400elsewhere required modified treatment and completion designs to succeed, often with more viscous fracturing fluids (lineargels or crosslinked gel) and bigger proppants (Stegent et al., 2010). These variatio
19、ns are often credited to differences in thehardness of the rock or the interaction with natural fractures due to their fabric, their density and the horizontal stressanisotropy of the formation.Some of the industry wide best practices are related to the size of the pad, the initial low proppant conc
20、entration, and the needfor a high number of fracturing stages. Nevertheless, each operator has his own approach even when drilling in the same area,based on his own past experience and economic/logistic constrains. Therefore, there is a need of a better understanding of theprocesses involved during
21、hydraulic fracturing, a better use of available data (rock properties, zones, stress field, etc.), and abetter evaluation of risk and uncertainties, in order to make better decisions when designing a treatment. This is whynumerical simulation workflows dedicated to shale are being developed.Today, s
22、everal simulators exist to assist the design of an optimum treatment by predicting the production outcome based onknown properties of the reservoir, the completion and the equations describing the physics of fracturing and production.These tools can be integrated into simulation workflows starting w
23、ith a hydraulic fracturing simulator for shale to predictfracture network geometry and proppant placement, then predicting the production with a numerical or semi-analyticalreservoir simulator. For example, Mirzaei et al. (2012) presented a simulation workflow linking the Unconventional FractureMode
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