Analysis of hydraulic fracture initiation and vertical propagation behavior in laminated shale formation

Tan, Ping; Jin, Yan; Han, Ke; Hou, Bing; Chen, Mian; Guo, Xiao‐Feng; Gao, Jie

doi:10.1016/j.fuel.2017.05.033

Cited by 277 publications

(84 citation statements)

References 23 publications

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“…Usually, the fracture breakdown is defined as the time point when the pressure in wellbore reaches the maximum, this means that fracture breakdown typically occurs after the point of initiation [53][54][55]. The fracture-initiation pressure is the time point when a tiny defect near borehole begins to propagate and the breakdown pressure is usually larger than the fracture-initiation pressure [41,56].…”

Section: The Effect Of Flow Rate On the Fracture Breakdown Pressurementioning

confidence: 99%

Experimental Study of Fracture Propagation: The Application in Energy Mining

Cheng

Zhang

2020

Energies

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Hydraulic fracturing has been widely used in recent years as a key technology to improve energy mining efficiency in petroleum and geothermal industries. Laboratory hydraulic fracturing experiments recently were completed in six large-scale 300 × 300 × 300 mm rock specimens to better understand this complex process of hydraulic fracturing. When injection flow rate increases from 5 to 30 mL/min. The fracture initiation pressures and breakdown pressures increase, the propagation times and post-fracturing pressures decrease. The fracture geometries are observed and analyzed, mean injection power is proposed and results show that it could be used to roughly estimate the fracture total lengths. Moreover, the fracture permeabilities based on the pressure data are calculated and linearly ascend with the increase of injection flow rates. These results can provide some reasonable advice for implementing hydraulic fracturing reservoir simulations and improving energy production efficiency on application to field-scale operation.Hydraulic fracturing usually relates complicated solid-fluid coupling processes. Due to the compactness and the low permeability of the granite, an intact large-size granite sample requires a high fracturing pressure to trigger the fracture. To better understand the characteristics of hydraulic fracturing process and fracture network after hydraulic fracturing. In this work, we carried out laboratorial hydraulic fracturing experiments with a true triaxial fracturing apparatus designed by Jilin University. Its cubic specimen fracturing capsule size is 300 × 300 × 300 mm. The granite samples were collected from the Songliao Basin petroleum reservoir field in the northeastern part of China. In order to investigate the injection flow rate on hydraulic fracturing chrematistics, we conducted hydraulic fracturing tests at different injection flow rates for six rocks. The initiation pressure, breakdown pressure, post-fracturing pressure, and propagation time were analyzed based on the fracturing pressure curves. The rock specimens were cut in half after test and the fracture geometry was observed. Based on recorded pressure data and curves, the fracture permeabilities of all specimens were calculated. Results in this study could provide some reasonable advice for implementing hydraulic fracturing reservoir simulations and improving energy production efficiency on application to field-scale operation. Laboratorial Tests BackgroundThe granite samples used in this study are taken from a place nearby YS-2 well (Figure 1) in the Songliao Basin [39]. The YS-2 well (127.25 • E, 52.36 • N) is in the Daqing Oilfield about 78 km from Daqing City, The YS-2 well is a geothermal energy exploration well, and exploration data shows that the geothermal resources here are abundant. As large size intact rock samples cannot be gotten from a wellbore. We use the outcrop rock samples as substitutes (Figure 2a). Three independent triaxial principal stresses are applied on cube-shaped samples to simulate the real field in-situ st...

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Section: The Effect Of Flow Rate On the Fracture Breakdown Pressurementioning

confidence: 99%

Experimental Study of Fracture Propagation: The Application in Energy Mining

Cheng

Zhang

2020

Energies

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“…Siebrits argued that the in‐situ stress field will change after the initial hydraulic fracturing, and the fracture initiation will start along the planes of different angles; the influential factors for the length and angle of refractures were studied by numerical simulation . Peng Tan and Tiankui Guo studied the influences of multiple factors on fracture propagation and fracture morphology based on a series of physical experiments . Song provided an innovative method to analyze time‐dependent deformation of material at fracture tip and its effect on propagation of hydraulically induced fractures by incorporating visco‐elastic behavior .…”

Section: Introductionmentioning

confidence: 99%

“…10 Peng Tan and Tiankui Guo studied the influences of multiple factors on fracture propagation and fracture morphology based on a series of physical experiments. 11,12 Song provided an innovative method to analyze time-dependent deformation of material at fracture tip and its effect on propagation of hydraulically induced fractures by incorporating visco-elastic behavior. 13 Taleghani studied the hydraulic fracture propagation in naturally fractured formation via numerical simulation and indicated the importance of nonlinear fracture tip effects as in-situ stress differences increase.…”

Section: Introductionmentioning

confidence: 99%

Study on the mechanisms of refracturing technology featuring temporary plug for fracturing fluid diversion in tight sandstone reservoirs

Zhao

et al. 2018

Energy Science & Engineering

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Well production rates in unconventional plays usually decline dramatically in the first year. Refracturing, which is a remedial production operation, is often done because original hydraulic fracturing failed to contribute any significant amount of flow or significant unfractured pay exists in the well. In order to maximize the fracturing fluid contact with the intact rock and to stimulate more reservoir volume in previously stimulated wells, a refracturing technology featuring a novel temporary plugging for fluid diversion is developed to enable the fracturing fluid to reach the untouched areas and to create reoriented fractures. In this paper, laboratory physical simulation tests of refracturing using fiber for effective temporary plugging is carried out to study the refracture morphology and the influencing factors of refractures. Results show that the refracture morphology is affected by the horizontal stress difference, the injection rate of initial fracturing fluid, and the natural fractures. Under condition of the different horizontal stress differences, the fracture initiation and orientation angle are different. When the horizontal stress difference is small, it is easy to form large angle fractures. The injection rate of initial fracturing fluid affects the length of initial fractures and refractures. The smaller the initial fracturing fluid injection rate is, the better the effect of temporary plugging in refracturing. The presence of natural fractures will lead to reorientation of refractures to form a complex fracture network. This study provides a theoretical guidance and technology support for refracturing operations.

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“…However, with the production decline of conventional reserves, the petroleum industry has shifted more towards the development and production of unconventional hydrocarbon resources. In this sense, improving gas recovery from unconventional gas resources such as shale gas [1][2][3][4] and tight gas [5][6][7] reservoirs using the hydraulic fracturing technology has proved to be effective in supplying a part of the increasing global energy demand. Some examples of hydraulic fracturing applications have been reported all around the world [8][9][10][11][12].…”

Section: Introductionmentioning

confidence: 99%

Modeling the Risk of Commercial Failure for Hydraulic Fracturing Projects Due to Reservoir Heterogeneity

et al. 2018

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Abstract:Hydraulic fracturing technologies play a major role in the global energy supply and affect oil pricing. The current oil price fluctuations within 40 to 55 USD per barrel have caused diminished economical margins for hydraulic fracturing projects. Hence, successful decision making the for execution of hydraulic fracturing projects requires a higher level of integration of technical, commercial, and uncertainty analyses. However, the complexity of hydraulic fracturing modeling, and the sensitivity and the effects of uncertainty of reservoir heterogeneity on well performance renders the integration of such studies rather impractical. The impact of reservoir heterogeneity on hydraulic fracturing performance has been quantified by the introduction of Heterogeneity Impact Factor (HIF) and formulas have been developed to forecast well performance using HIF. These advances provide a platform for introducing a practical approach for introducing the Risk of Commercial Failure (RCF) due to reservoir heterogeneity in hydraulic fracturing projects. This paper defines such a parameter and the methodology to calculate it in a time-efficient manner. The proposed approach has been exercised on a real project in which a RCF of 20% is computed. The analysis also covers the sensitivity on Capital Expenditure (CAPEX), Operational Expenditure (OPEX), gas price, HIF and discount rate.

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Analysis of hydraulic fracture initiation and vertical propagation behavior in laminated shale formation

Cited by 277 publications

References 23 publications

Experimental Study of Fracture Propagation: The Application in Energy Mining

Experimental Study of Fracture Propagation: The Application in Energy Mining

Study on the mechanisms of refracturing technology featuring temporary plug for fracturing fluid diversion in tight sandstone reservoirs

Modeling the Risk of Commercial Failure for Hydraulic Fracturing Projects Due to Reservoir Heterogeneity

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