A multiscale-multiphase simulation model for the evaluation of shale gas recovery coupled the effect of water flowback

    Research output: Contribution to journalArticle

    21 Citations (Scopus)

    Abstract

    After fracturing operation, hydraulic fractures and induced fractures are created within the shale reservoir. A lot of treatment water is stored in fractures network and flow back into the surface during the gas recovery process. The gas production performance is affected by the water flowback because two phase flow occurs within fractures zone. For the created reservoir scale, we propose a multiscale- multiphase simulation model, which defines the whole domain as three sections. Section A contains the organic and inorganic matrix, which stores both the free gas and adsorbed gas. Flow processes are defined in the components of inorganic minerals and kerogens, respectively. For the section B and C, gas phase and water phase are existed together. Under this framework, a set of partial differential equations are derived to define various liquid transport processes: (1) gas flow in the kerogen system of matrix; (2) gas flow in the inorganic system of matrix; (3) gas-water two phase flow in fractures zone and (4) gas-water two phase flow in the hydraulic fracture system. Dynamic permeability models and mass exchanges between them are coupled for all systems. The model was verified against field production data from the Barnett Shale. Model simulation results show that flowback of treatment water can significantly affect the gas production rate at the early stage. Firstly, the increase of maximum water relative permeability can raise the water flowback rate and gas production rate but increasing non-wetting phase entry pressure will decrease the fluids flow rate. Secondly, the impact of fractures zone width on gas production performance is unstable and increasing initial water saturation can increase the water flowback rate but decrease gas production rate. Overall, the dynamic performances of water phase within fractures zone have significant impact on the short and long time shale gas recovery. 

    Original languageEnglish
    Pages (from-to)191-205
    Number of pages15
    JournalFuel
    Volume199
    DOIs
    Publication statusPublished - 1 Jul 2017

    Fingerprint

    Gases
    Recovery
    Water
    Two phase flow
    Kerogen
    Shale
    Water treatment
    Flow of gases
    Shale gas
    Hydraulics
    Partial differential equations
    Minerals
    Flow of fluids
    Flow rate
    Liquids

    Cite this

    @article{13332eae7142466b8310af72dc10befe,
    title = "A multiscale-multiphase simulation model for the evaluation of shale gas recovery coupled the effect of water flowback",
    abstract = "After fracturing operation, hydraulic fractures and induced fractures are created within the shale reservoir. A lot of treatment water is stored in fractures network and flow back into the surface during the gas recovery process. The gas production performance is affected by the water flowback because two phase flow occurs within fractures zone. For the created reservoir scale, we propose a multiscale- multiphase simulation model, which defines the whole domain as three sections. Section A contains the organic and inorganic matrix, which stores both the free gas and adsorbed gas. Flow processes are defined in the components of inorganic minerals and kerogens, respectively. For the section B and C, gas phase and water phase are existed together. Under this framework, a set of partial differential equations are derived to define various liquid transport processes: (1) gas flow in the kerogen system of matrix; (2) gas flow in the inorganic system of matrix; (3) gas-water two phase flow in fractures zone and (4) gas-water two phase flow in the hydraulic fracture system. Dynamic permeability models and mass exchanges between them are coupled for all systems. The model was verified against field production data from the Barnett Shale. Model simulation results show that flowback of treatment water can significantly affect the gas production rate at the early stage. Firstly, the increase of maximum water relative permeability can raise the water flowback rate and gas production rate but increasing non-wetting phase entry pressure will decrease the fluids flow rate. Secondly, the impact of fractures zone width on gas production performance is unstable and increasing initial water saturation can increase the water flowback rate but decrease gas production rate. Overall, the dynamic performances of water phase within fractures zone have significant impact on the short and long time shale gas recovery. ",
    keywords = "Multiscale, Reservoir simulation, Shale gas, Two phase flow, Water flowback",
    author = "Peng Cao and Jishan Liu and Leong, {Yee Kwong}",
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    day = "1",
    doi = "10.1016/j.fuel.2017.02.078",
    language = "English",
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    A multiscale-multiphase simulation model for the evaluation of shale gas recovery coupled the effect of water flowback. / Cao, Peng; Liu, Jishan; Leong, Yee Kwong.

    In: Fuel, Vol. 199, 01.07.2017, p. 191-205.

    Research output: Contribution to journalArticle

    TY - JOUR

    T1 - A multiscale-multiphase simulation model for the evaluation of shale gas recovery coupled the effect of water flowback

    AU - Cao, Peng

    AU - Liu, Jishan

    AU - Leong, Yee Kwong

    PY - 2017/7/1

    Y1 - 2017/7/1

    N2 - After fracturing operation, hydraulic fractures and induced fractures are created within the shale reservoir. A lot of treatment water is stored in fractures network and flow back into the surface during the gas recovery process. The gas production performance is affected by the water flowback because two phase flow occurs within fractures zone. For the created reservoir scale, we propose a multiscale- multiphase simulation model, which defines the whole domain as three sections. Section A contains the organic and inorganic matrix, which stores both the free gas and adsorbed gas. Flow processes are defined in the components of inorganic minerals and kerogens, respectively. For the section B and C, gas phase and water phase are existed together. Under this framework, a set of partial differential equations are derived to define various liquid transport processes: (1) gas flow in the kerogen system of matrix; (2) gas flow in the inorganic system of matrix; (3) gas-water two phase flow in fractures zone and (4) gas-water two phase flow in the hydraulic fracture system. Dynamic permeability models and mass exchanges between them are coupled for all systems. The model was verified against field production data from the Barnett Shale. Model simulation results show that flowback of treatment water can significantly affect the gas production rate at the early stage. Firstly, the increase of maximum water relative permeability can raise the water flowback rate and gas production rate but increasing non-wetting phase entry pressure will decrease the fluids flow rate. Secondly, the impact of fractures zone width on gas production performance is unstable and increasing initial water saturation can increase the water flowback rate but decrease gas production rate. Overall, the dynamic performances of water phase within fractures zone have significant impact on the short and long time shale gas recovery. 

    AB - After fracturing operation, hydraulic fractures and induced fractures are created within the shale reservoir. A lot of treatment water is stored in fractures network and flow back into the surface during the gas recovery process. The gas production performance is affected by the water flowback because two phase flow occurs within fractures zone. For the created reservoir scale, we propose a multiscale- multiphase simulation model, which defines the whole domain as three sections. Section A contains the organic and inorganic matrix, which stores both the free gas and adsorbed gas. Flow processes are defined in the components of inorganic minerals and kerogens, respectively. For the section B and C, gas phase and water phase are existed together. Under this framework, a set of partial differential equations are derived to define various liquid transport processes: (1) gas flow in the kerogen system of matrix; (2) gas flow in the inorganic system of matrix; (3) gas-water two phase flow in fractures zone and (4) gas-water two phase flow in the hydraulic fracture system. Dynamic permeability models and mass exchanges between them are coupled for all systems. The model was verified against field production data from the Barnett Shale. Model simulation results show that flowback of treatment water can significantly affect the gas production rate at the early stage. Firstly, the increase of maximum water relative permeability can raise the water flowback rate and gas production rate but increasing non-wetting phase entry pressure will decrease the fluids flow rate. Secondly, the impact of fractures zone width on gas production performance is unstable and increasing initial water saturation can increase the water flowback rate but decrease gas production rate. Overall, the dynamic performances of water phase within fractures zone have significant impact on the short and long time shale gas recovery. 

    KW - Multiscale

    KW - Reservoir simulation

    KW - Shale gas

    KW - Two phase flow

    KW - Water flowback

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    U2 - 10.1016/j.fuel.2017.02.078

    DO - 10.1016/j.fuel.2017.02.078

    M3 - Article

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    EP - 205

    JO - Fuel

    JF - Fuel

    SN - 0016-2361

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