Radial permeability measurement for shale using variable pressure gradients

Kunkun Fan, Renyuan Sun, Derek Elsworth, Mingzhe Dong, Yajun Li, Congbin Yin, Yanchao Li

Research output: Contribution to conferencePaper

1 Citation (Scopus)

Abstract

Shale gas is becoming an important addition to worldwide energy supply with permeability a critical controlling factor for gas production. Helium permeability determined using small pressure gradient (SPG)methods may lead to erroneous results when applied to actual field production with variable pressure gradients (VPG). In this paper, a VPG method using real gas (rather than He) is established to render permeability measurements more representative of reservoir conditions and hence response. Dynamic methane production experiments are performed to measure permeability using the annular space in shale cores. Boundary pressure is maintained constant within each production stage with a designated pressure gradient and the gas production with time is measured. A mathematical model explicitly accommodating gas desorption uses pseudo-pressure and normalized time to accommodate the effects of variations in pressure-dependent viscosity and compressibility. General and approximate solutions to the model are obtained and discussed. These provide a convenient approach to estimate radial permeability in the core by nonlinear fitting to match the approximate solution with the recorded gas production data. Results indicate that the radial permeability of the shale determined with methane is of the order of of 10-6-10-5md and decreases with an increase in average pore pressure. This is contrary to the observed change in permeability estimated with helium. Permeability errors obtained from the SPG method using helium are several times greater than those obtained from the VPG method using methane. Bedding geometry has a significant influence on shale permeability. The superiority of the VPG method is confirmed by comparing permeability test results obtained from both VPG and SPG methods. The VPG method has two advantages: The first is that reservoir gas can be used in the VPG method instead of helium, better incorporating potential desorption impacts in permeability evltuion. The second is that realistic pressure dependent impacts can be accurately accommodated, making this method more applicable to gas production conditions in the reservoir. Although several assumptions are used, the results obtained from the VPG method are much closer to reality and may be directly used for actual gas production evaluation and prediction.

Original languageEnglish (US)
StatePublished - Jan 1 2018
EventSPE Trinidad and Tobago Section Energy Resources Conference 2018 - Port of Spain, Trinidad and Tobago
Duration: Jun 25 2018Jun 26 2018

Other

OtherSPE Trinidad and Tobago Section Energy Resources Conference 2018
CountryTrinidad and Tobago
CityPort of Spain
Period6/25/186/26/18

Fingerprint

Shale
Pressure gradient
pressure gradient
Gradient methods
shale
permeability
Gases
Helium
gas production
helium
Methane
methane
Desorption
desorption
method
Pore pressure
compressibility
Compressibility
gas
pore pressure

All Science Journal Classification (ASJC) codes

  • Geotechnical Engineering and Engineering Geology
  • Geochemistry and Petrology
  • Fuel Technology

Cite this

Fan, K., Sun, R., Elsworth, D., Dong, M., Li, Y., Yin, C., & Li, Y. (2018). Radial permeability measurement for shale using variable pressure gradients. Paper presented at SPE Trinidad and Tobago Section Energy Resources Conference 2018, Port of Spain, Trinidad and Tobago.
Fan, Kunkun ; Sun, Renyuan ; Elsworth, Derek ; Dong, Mingzhe ; Li, Yajun ; Yin, Congbin ; Li, Yanchao. / Radial permeability measurement for shale using variable pressure gradients. Paper presented at SPE Trinidad and Tobago Section Energy Resources Conference 2018, Port of Spain, Trinidad and Tobago.
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Fan, K, Sun, R, Elsworth, D, Dong, M, Li, Y, Yin, C & Li, Y 2018, 'Radial permeability measurement for shale using variable pressure gradients' Paper presented at SPE Trinidad and Tobago Section Energy Resources Conference 2018, Port of Spain, Trinidad and Tobago, 6/25/18 - 6/26/18, .

Radial permeability measurement for shale using variable pressure gradients. / Fan, Kunkun; Sun, Renyuan; Elsworth, Derek; Dong, Mingzhe; Li, Yajun; Yin, Congbin; Li, Yanchao.

2018. Paper presented at SPE Trinidad and Tobago Section Energy Resources Conference 2018, Port of Spain, Trinidad and Tobago.

Research output: Contribution to conferencePaper

TY - CONF

T1 - Radial permeability measurement for shale using variable pressure gradients

AU - Fan, Kunkun

AU - Sun, Renyuan

AU - Elsworth, Derek

AU - Dong, Mingzhe

AU - Li, Yajun

AU - Yin, Congbin

AU - Li, Yanchao

PY - 2018/1/1

Y1 - 2018/1/1

N2 - Shale gas is becoming an important addition to worldwide energy supply with permeability a critical controlling factor for gas production. Helium permeability determined using small pressure gradient (SPG)methods may lead to erroneous results when applied to actual field production with variable pressure gradients (VPG). In this paper, a VPG method using real gas (rather than He) is established to render permeability measurements more representative of reservoir conditions and hence response. Dynamic methane production experiments are performed to measure permeability using the annular space in shale cores. Boundary pressure is maintained constant within each production stage with a designated pressure gradient and the gas production with time is measured. A mathematical model explicitly accommodating gas desorption uses pseudo-pressure and normalized time to accommodate the effects of variations in pressure-dependent viscosity and compressibility. General and approximate solutions to the model are obtained and discussed. These provide a convenient approach to estimate radial permeability in the core by nonlinear fitting to match the approximate solution with the recorded gas production data. Results indicate that the radial permeability of the shale determined with methane is of the order of of 10-6-10-5md and decreases with an increase in average pore pressure. This is contrary to the observed change in permeability estimated with helium. Permeability errors obtained from the SPG method using helium are several times greater than those obtained from the VPG method using methane. Bedding geometry has a significant influence on shale permeability. The superiority of the VPG method is confirmed by comparing permeability test results obtained from both VPG and SPG methods. The VPG method has two advantages: The first is that reservoir gas can be used in the VPG method instead of helium, better incorporating potential desorption impacts in permeability evltuion. The second is that realistic pressure dependent impacts can be accurately accommodated, making this method more applicable to gas production conditions in the reservoir. Although several assumptions are used, the results obtained from the VPG method are much closer to reality and may be directly used for actual gas production evaluation and prediction.

AB - Shale gas is becoming an important addition to worldwide energy supply with permeability a critical controlling factor for gas production. Helium permeability determined using small pressure gradient (SPG)methods may lead to erroneous results when applied to actual field production with variable pressure gradients (VPG). In this paper, a VPG method using real gas (rather than He) is established to render permeability measurements more representative of reservoir conditions and hence response. Dynamic methane production experiments are performed to measure permeability using the annular space in shale cores. Boundary pressure is maintained constant within each production stage with a designated pressure gradient and the gas production with time is measured. A mathematical model explicitly accommodating gas desorption uses pseudo-pressure and normalized time to accommodate the effects of variations in pressure-dependent viscosity and compressibility. General and approximate solutions to the model are obtained and discussed. These provide a convenient approach to estimate radial permeability in the core by nonlinear fitting to match the approximate solution with the recorded gas production data. Results indicate that the radial permeability of the shale determined with methane is of the order of of 10-6-10-5md and decreases with an increase in average pore pressure. This is contrary to the observed change in permeability estimated with helium. Permeability errors obtained from the SPG method using helium are several times greater than those obtained from the VPG method using methane. Bedding geometry has a significant influence on shale permeability. The superiority of the VPG method is confirmed by comparing permeability test results obtained from both VPG and SPG methods. The VPG method has two advantages: The first is that reservoir gas can be used in the VPG method instead of helium, better incorporating potential desorption impacts in permeability evltuion. The second is that realistic pressure dependent impacts can be accurately accommodated, making this method more applicable to gas production conditions in the reservoir. Although several assumptions are used, the results obtained from the VPG method are much closer to reality and may be directly used for actual gas production evaluation and prediction.

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M3 - Paper

ER -

Fan K, Sun R, Elsworth D, Dong M, Li Y, Yin C et al. Radial permeability measurement for shale using variable pressure gradients. 2018. Paper presented at SPE Trinidad and Tobago Section Energy Resources Conference 2018, Port of Spain, Trinidad and Tobago.