A research into thermal field in fluid-saturated porous media

Valiullin, R.A.; Sharafutdinov, R. F.; Ramazanov, Ayrat

doi:10.1016/j.powtec.2004.09.023

Cited by 11 publications

(3 citation statements)

References 2 publications

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“…Sagar et al (1989) considered Joule-Thomson effects as a possible heat source/sink during fluid flow and applied the model to estimate heat losses in gas flow. Valiullin et al (2004) presented a treatment of the temperature distribution in the formation when the pressure field in the reservoir changes, and showed that indeed, adiabatic and Joule-Thomson effects as well as effects due to heat of phase transition (gas liberation from oil) may be present during fluid flow in a hydrocarbon saturated porous medium. Valiullin et al (2004) designed experiments to estimate the thermodynamic coefficients, namely the Joule-Thomson coefficient and adiabatic coefficients.…”

Section: Previous Workmentioning

confidence: 99%

“…Valiullin et al (2004) presented a treatment of the temperature distribution in the formation when the pressure field in the reservoir changes, and showed that indeed, adiabatic and Joule-Thomson effects as well as effects due to heat of phase transition (gas liberation from oil) may be present during fluid flow in a hydrocarbon saturated porous medium. Valiullin et al (2004) designed experiments to estimate the thermodynamic coefficients, namely the Joule-Thomson coefficient and adiabatic coefficients. Ramazanov and Parshin (2006) went on to develop an analytical model that described the formation temperature distribution in a reservoir, while accounting for phase transitions.…”

Section: Previous Workmentioning

confidence: 99%

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Modeling of Reservoir Temperature Transients and Parameter Estimation Constrained to the Model

Duru

2008

All Days

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Permanent downhole gauges (PDGs) provide a continuous source of downhole pressure, temperature and sometimes rate data. Until recently, the measured temperature data have been largely ignored. However, a close observation of the temperature measurements reveals that the temperature responds to changes in flow rate and pressure, which implies that the temperature data may be a source of reservoir information.In this work, the Alternating Conditional Expectations (ACE) technique was applied to temperature and flow rate signals from PDGs to establish the existence of a functional relationship between them. Then, performing energy, mass and momentum balances, reservoir temperature transient models were developed for flow of single-and multiphase fluids, as functions of formation parameters, fluid properties, and changes in rate and pressure. The pressure fields in oil and gas bearing formations are usually transient. This gives rise to pressure-temperature effects appearing as temperature changes in the porous medium when the pressure field changes. The magnitudes of these effects depend on the properties of the formation, flow geometry, time and other factors and result in a reservoir temperature distribution that is changing in both space and time. Therefore, in this study, reservoir thermometric effects were modeled as convective, conductive and transient phenomena with consideration for time and space dependencies. This mechanistic model included the Joule-Thomson effects due to fluid compressibility, and viscous dissipation in the reservoir during fluid flow in accounting for the reservoir temperature dependence on changing pressure/flowrate fields.Numerical solution schemes as well as the semianalytical scheme -Operator Splitting and Time Stepping (OSATS) were used to solve the models, and the solutions closely reproduced the temperature profiles seen in real measured data. By matching the models to different temperature transient histories obtained from PDGs, reservoir parameters namely porosity and saturation and fluid Joule-Thomson coefficient could be estimated. Hence the normally unused temperature data record can be used to estimate reservoir parameters not usually available from conventional well test analysis. Analysis of temperature may also provide a less expensive substitute for downhole flow rate measurement.

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Section: Previous Workmentioning

confidence: 99%

Section: Previous Workmentioning

confidence: 99%

Modeling of Reservoir Temperature Transients and Parameter Estimation Constrained to the Model

Duru

2008

All Days

View full text Add to dashboard Cite

show abstract

“…Again, in orders of magnitude, these temperature measurements compare with those seen for oil and gas systems. Valiullin et al (2004) presented a simplified treatment of the temperature distribution in the formation when the pressure field in the reservoir changes. They showed that adiabatic and Joule-Thomson effects and effects caused by heat of phase transition (gas liberation from oil) may be present during fluid flow in a hydrocarbon-saturated porous medium.…”

Section: Introductionmentioning

confidence: 99%

Modeling Reservoir Temperature Transients and Reservoir-Parameter Estimation Constrained to the Model

Duru

Horne

2010

SPE Reservoir Evaluation &Amp; Engineering

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Permanent downhole gauges (PDGs) provide a continuous source of downhole pressure, temperature, and sometimes flow-rate data. Until recently, the measured temperature data have been largely ignored, although a close observation of the temperature measurements reveals a response to changes in flow rate and pressure. This suggests that the temperature measurements may be a useful source of reservoir information. In this study, reservoir temperature-transient models were developed for single-and multiphase-fluid flows, as functions of formation parameters, fluid properties, and changes in flow rate and pressure. The pressure fields in oil-and gas-bearing formations are usually transient, and this gives rise to pressure/temperature effects appearing as temperature change. The magnitudes of these effects depend on the properties of the formation, flow geometry, time, and other factors and result in a reservoir temperature distribution that is changing in both space and time. In this study, these thermometric effects were modeled as convective, conductive, and transient phenomena with consideration for time and space dependencies. This mechanistic model included the Joule-Thomson effects resulting from fluid compressibility and viscous dissipation in the reservoir during fluid flow. Because of the nature of the models, the semianalytical solution technique known as operator splitting was used to solve them, and the solutions were compared to synthetic and real temperature data. In addition, by matching the models to different temperaturetransient histories obtained from PDGs, reservoir parameters such as average porosity, near-well permeabilities, saturation, and some thermal properties of the fluid and formation could be estimated. A key target of this work was to show that temperature measurements, often ignored, can be used to estimate reservoir parameters, as a complement to other more-conventional techniques.

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Multi-stage hydraulic fracturing and radio-frequency electromagnetic radiation for heavy-oil production

Davletbaev

Kovaleva

Nasyrov

et al. 2015

Journal of Unconventional Oil and Gas Resources

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A research into thermal field in fluid-saturated porous media

Cited by 11 publications

References 2 publications

Modeling of Reservoir Temperature Transients and Parameter Estimation Constrained to the Model

Modeling of Reservoir Temperature Transients and Parameter Estimation Constrained to the Model

Modeling Reservoir Temperature Transients and Reservoir-Parameter Estimation Constrained to the Model

Multi-stage hydraulic fracturing and radio-frequency electromagnetic radiation for heavy-oil production

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