Multiphase Fluid-Loss Properties and Return Permeability of Energized Fracturing Fluids

Ribeiro, Lionel H.; Sharma, Mukul M.

doi:10.2118/139622-pa

Cited by 30 publications

(22 citation statements)

References 15 publications

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“…The shear modulus is calculated using

μ = V_{s}^{2} ρ_{m} (\sim 17.4 GPa)

. The viscosity of the slurry is around 0.025–0.15 Pa s [ Ribeiro and Sharma , ], which is significantly larger than the viscosity of water (0.001 Pa s).…”

Section: Discussion and Implications For Hydraulic Fracturing Mechanismsmentioning

confidence: 99%

Interpretation of resonance frequencies recorded during hydraulic fracturing treatments

Tary

Baan

Eaton

2014

J. Geophys. Res. Solid Earth

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Hydraulic fracturing treatments are often monitored by strings of geophones deployed in boreholes. Instead of picking discrete events only, we here use time‐frequency representations of continuous recordings to identify resonances in two case studies. This paper outlines an interpretational procedure to identify their cause using a subdivision into source, path, and receiver‐side effects. For the first case study, two main resonances are observed both at depth by the downhole geophones and on the surface by two broadband arrays. The two acquisition networks have different receiver and path effects, yet recorded the same resonances; these resonances are therefore likely generated by source effects. The amplitude pattern at the surface arrays indicates that these resonances are probably due to pumping operations. In the second case study, selective resonances are detected by the downhole geophones. Resonances coming from receiver effects are either lower or higher frequency, and wave propagation modeling shows that path effects are not significant. We identify two possible causes within the source area, namely, eigenvibrations of fractures or non‐Darcian flow within the hydraulic fractures. In the first situation, 15–10 m long fluid‐filled cracks could generate the observed resonances. An interconnected fracture network would then be required, corresponding to mesoscale deformation of the reservoir. Alternatively, systematic patterns in non‐Darcian fluid flow within the hydraulic fracture could also be their leading cause. Resonances can be used to gain a better understanding of reservoir deformations or dynamic fluid flow perturbations during fluid injection into hydrocarbon and geothermal reservoirs, CO2 sequestration, or volcanic eruptions.

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“…The shear modulus is calculated using

μ = V_{s}^{2} ρ_{m} (\sim 17.4 GPa)

. The viscosity of the slurry is around 0.025–0.15 Pa s [ Ribeiro and Sharma , ], which is significantly larger than the viscosity of water (0.001 Pa s).…”

Section: Discussion and Implications For Hydraulic Fracturing Mechanismsmentioning

confidence: 99%

Interpretation of resonance frequencies recorded during hydraulic fracturing treatments

Tary

Baan

Eaton

2014

J. Geophys. Res. Solid Earth

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“…Compared with conventional fracturing fluids, no filter cake exists in the fracture when the SC‐CO 2 penetrates the unconventional natural gas reservoir. The reservoir formation can be divided into the invasion region and the undisturbed gas reservoir region . For conventional hydraulic fracturing, it is normally assumed that the fracturing fluid is incompressible, and parameters, such as its density and viscosity, are constant; therefore, the Joule–Thomson coefficient term is usually ignored, as shown in Figure .…”

Section: Two‐phase Filtration Rate Modelmentioning

confidence: 99%

Study on filtration patterns of supercritical CO₂ fracturing in unconventional natural gas reservoirs

et al. 2017

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Taking the supercritical CO2 (SC‐CO2) Joule–Thomson coefficient and the effects of adsorption between CO2‐shale‐CH4 into consideration, a two‐phase filtration rate calculation model of SC‐CO2 fracturing in unconventional natural gas reservoirs is proposed. With the help of an experimental apparatus of fluid filtration in shales, it has been found that the theoretical calculation and experimental measurement have an absolute error of 3.31% of the steady filtration rate under specific conditions. Under different pressure differentials between the reservoir and the fracture, the absolute average error of the calculated filtration rate is 2.53%, compared with the experimental data. The filtration of the SC‐CO2 fracturing in an unconventional natural gas reservoir is characterized by the filtration rate, which gradually decreases with time, and the rate of its decrease tends to reach equilibrium in the late stage. The funnel‐like pressure distribution occurs near the fracture during the transmission of the filtration pressure. A non‐linear relationship exists between the filtration rate and the permeability, which indicates that higher permeability enlarges the effective range of the fracturing fluid pressure as well as the invasion region. Moreover, the steady filtration rate and the pressure drop magnitude present a nearly linear increase with the increasing filtration pressure differential. In the site operation of the SC‐CO2 fracturing, the injection temperature, pressure, and pump rate can be optimized using the proposed chart. Thickening of the SC‐CO2 fracturing fluid can effectively decrease the filtration rate, and thus development of thickened SC‐CO2 fracturing fluid systems that prevent formation damage is needed. © 2017 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…Lab experiment on fluid lose remains to be the most efficient tool to study the multi-phase fluid leak off(K.E. Friehauf, 2009;Harris, 1983Harris, , 1987Ribeiro & Sharma, 2012). Researches have indicated that foam fracturing fluid has excellent performance on reducing fluid leak off; filter cake can form on fracture surface when wall-building materials such as hydroxypropyl guar (HPG) is added; bubbles can accumulate on the surface of fracture or filter cake; foam can leak off into and penetrate high permeable (~100mD) core, while the two phases can penetrate lower permeable (~10mD) core with different quality from inlet foam; the leak off coefficient depends on foam quality, continuous phase viscosity(wall-building material content), permeability and pressure difference.…”

Section: Multi-phase Fluid Leak Offmentioning

confidence: 99%

“…Therefore, N 2 -energized fluid, CO 2 -energized fluid, N 2 -foam and CO 2 -foam have been widely applied especially in water-sensitive formation. These multi-phase energized fracturing fluids are able to help control fluid leak off and assist load fluid recovery during flow back, and are called foam if the volume percentage of gas to the total fluid is higher than 52% (Ribeiro & Sharma, 2012). This study focuses on the static fluid leak off after fracturing, flow back efficiency of different fracturing fluids and the influence of formation damage on well after-stimulation productivity.…”

Section: Introductionmentioning

confidence: 99%

Minimize Formation Damage in Water-Sensitive Unconventional Reservoirs by Using Energized Fracturing Fluid

Kong

Wang

Chen

et al. 2016

SPE International Conference and Exhibition on Formation Damage Control

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Slickwater has been widely used for hydraulic fracturing as it is inexpensive and able to carry proppants into the fracture. However, such fluid is unsuitable for water-sensitive formations, such as Montney. Water saturation around the fracture increases and clay swells when water leaks-off into matrix, both hindering natural gas flowing from matrix into fractures. N 2 or CO 2 energized water-based fracturing fluids have been widely used in water-sensitive formation as they can minimize fluid leak off during fracturing and achieve higher load fluid recovery during flow back.In this paper, multi-phase numerical simulations are applied to study the formation damage mitigation in Montney tight reservoir by using energized fracturing fluid. A simulation model is built and history matched with flow back and early production data of a typical Montney tight gas well. The behavior of multi-phase fluid leak off and flow back is studied, and the sensitivity of foam quality of fracturing fluid on load fluid recovery and well after stimulation productivity is analyzed. Statistical analysis is conducted on the stimulation and production data of over 5000 Montney wells to study the performance of energized fracturing in water-sensitive Montney formation. It is found that multi-phase fracturing fluid has less dynamic fluid leak off than that of a single phase fracturing fluid (i.e., water), and the major fluid leak off occurs during the static leak off period between the end of the stimulation processes and start of the flow back. Gas phase penetrates deeper and faster into the reservoir matrix in comparison with the liquid phase, which greatly contributes to flow back of fracturing fluid. Formation damage caused by fracturing fluid leak off can affect both early and long term production. In addition, N 2 -foam leads to the highest load fluid recovery in Montney formation, which is 1.6 times of that of CO 2 -foam. This work provides critical insights into understanding the performance of using energized fracturing fluid to mitigate formation damage in tight formations.

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Multiphase Fluid-Loss Properties and Return Permeability of Energized Fracturing Fluids

Cited by 30 publications

References 15 publications

Interpretation of resonance frequencies recorded during hydraulic fracturing treatments

Interpretation of resonance frequencies recorded during hydraulic fracturing treatments

Study on filtration patterns of supercritical CO₂ fracturing in unconventional natural gas reservoirs

Minimize Formation Damage in Water-Sensitive Unconventional Reservoirs by Using Energized Fracturing Fluid

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Multiphase Fluid-Loss Properties and Return Permeability of Energized Fracturing Fluids

Cited by 30 publications

References 15 publications

Interpretation of resonance frequencies recorded during hydraulic fracturing treatments

Interpretation of resonance frequencies recorded during hydraulic fracturing treatments

Study on filtration patterns of supercritical CO2 fracturing in unconventional natural gas reservoirs

Minimize Formation Damage in Water-Sensitive Unconventional Reservoirs by Using Energized Fracturing Fluid

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Study on filtration patterns of supercritical CO₂ fracturing in unconventional natural gas reservoirs