Application of a proportional-integral control for the estimation of static formation temperatures in oil wells

Espinosa-Paredes, Gilberto; Morales-Díaz, A.; Olea-González, U.; Ambriz-García, J. J.

doi:10.1016/j.marpetgeo.2007.11.002

Cited by 34 publications

(17 citation statements)

References 16 publications

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“…Zschocke (2005) proposes a correction scheme for densely sampled temperature logs that are thermally disturbed by the drilling process and where no repeat measurements are available. Finally, the model proposed by Espinosa‐Paredes et al (2009) can estimate equilibrium formation temperatures from a single temperature measurement. In case the drilling history and the properties of the bore fluid are unknown Eppelbaum & Kutasov (2006) and Kutasov & Eppelbaum (2010) suggest a correction scheme based on three measured shut‐in temperatures for estimating the equilibrium formation temperature.…”

Section: Conclusion and Discussionmentioning

confidence: 99%

“…Espinosa‐Paredes et al (2009) develop a fully transient model which considers the heat‐transfer process by conduction in the well and conductive–convective heat transfer in the formation during shut‐in time and convective–conductive heat transfer during circulation in the drill pipe, drill pipe wall, annulus and formation with fluid circulation loss to the surrounding formation. They compare modelled temperatures to corresponding estimates from previously suggested models by Horner (1951) and Hasan & Kabir (1994).…”

Section: Introductionmentioning

confidence: 99%

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Estimation of the equilibrium formation temperature in the presence of bore fluid invasion

Poulsen

Nielsen

Balling

2012

Geophysical Journal International

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SUMMARY Bottom hole temperatures (BHTs) measured during drilling operations are thermally disturbed by the drilling process. This paper presents a method, CSMI (Cylindrical Source Model with Invasion of bore mud filtrate), for estimating equilibrium formation temperatures with probability distributions from BHT measurements in the presence of bore fluid invasion. The scheme is based on finite element analysis in conjunction with Markov chain Monte Carlo inversion. The axisymmetric forward model assumes a cylindrical source of finite radius and contrasting thermal parameters, which includes the possibility of invasion (advection) of mud filtrate into the formation. In a synthetic example, it is demonstrated that given bore fluid invasion and a low and high temperature of the bore mud and formation, respectively, the equilibrium formation temperature and the uncertainty hereon is underestimated by correction schemes based on purely conductive models. The influence of the borehole radius and fluid invasion on the temperature measured at the borehole axis attenuates over time. It is further demonstrated that the invasion radius and the matrix thermal conductivity cannot be estimated simultaneously with the CSMI scheme. The analysis of five BHT records measured onshore Denmark, for which the equilibrium formation temperature is known, shows that CSMI temperatures based on single datum records are highly uncertain because of a strong negative coupling between the temperature of the mud filtrate and the equilibrium formation temperature. For records with multiple temperature measurements, the CSMI scheme matches statistically the measured equilibrium formation temperatures. It is further shown that additional negative bias is added to Horner plot temperatures if bore fluid invasion has occurred. Allowing for bore fluid invasion in addition to a borehole of finite radius and contrasting thermal parameters, increases temperature estimates by 5 per cent (4–7 per cent) on average given that invasion is indicated and that the bore fluid is significantly colder than the formation. Indications of bore fluid invasion from CSMI analysis are confirmed in two examples by analysing corresponding caliper logs.

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Section: Conclusion and Discussionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Estimation of the equilibrium formation temperature in the presence of bore fluid invasion

Poulsen

Nielsen

Balling

2012

Geophysical Journal International

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“…They present a simple graphical correlation to estimate the length of this early transient period. Espionsa-Paredes et al (2008, 2009 presented a prediction model for the formation temperature. Sagar et al (1991) presented a simple model suitable for hand calculations to predict temperature profiles in two-phase flowing wells.…”

Section: Introductionmentioning

confidence: 99%

“…Hagoort (2005) presented a simple and physically transparent analytical solution for the prediction of well-bore temperatures in gas production wells. Espionsa-Paredes et al (2008, 2009) presented a prediction model for the formation temperature. In this research, models are built only for predicting temperature profiles that assume steady-state conditions, yet these models do not predict pressure profiles.…”

Section: Introductionmentioning

confidence: 99%

Prediction of temperature, pressure, density, velocity distribution in H‐T‐H‐P gas wells

Wang³

et al. 2011

Can J Chem Eng

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In this paper, we build a model of coupled differential equations concerning pressure, temperature density and velocity in H-T-H-P (High Temperature-High Pressure) gas wells according to the conservation of mass, momentum and energy. We present an algorithm-solving model by the fourth-order Runge-Kutta method. Basic data from the Dayi Well, 7100 m deep in China, are used for case history calculations and a sensitivity analysis is done for the model. Gas pressure, temperature, velocity and density along the depth of the well are plotted with different productions, different geothermal gradients and different thermal conductivities, intuitively reflecting gas flow law and the characteristics of heat transfer in formation. The results can provide a dynamic analysis of production for H-T-H-P gas wells.

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“…In the second approach the thermal interaction between the circulating fluid and the formation is approximated by the Newton relationship on the bore-face (Espinosa-Paredes et al, 2009;Fomin et al, 2003;Hasan and Kabir, 1994;Holmes and Swift, 1970;Keller et al, 1973;Raymond, 1969;Sump and Williams, 1973;Thompson and Burgess, 1985;Tragesser and Parker, 1972;Wooley, 1980). As correctly mentioned by Fomin et al (2003) the first approach can be used in the case of highly intensive heat transfer between the circulating fluid and surrounding rocks, which takes place for fully developed turbulent flow in the well.…”

Section: Introductionmentioning

confidence: 99%

Determination of the formation temperature from shut-in logs: Estimation of the radius of thermal influence

Eppelbaum

Kutasov²

2011

Journal of Applied Geophysics

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Application of a proportional-integral control for the estimation of static formation temperatures in oil wells

Cited by 34 publications

References 16 publications

Estimation of the equilibrium formation temperature in the presence of bore fluid invasion

Estimation of the equilibrium formation temperature in the presence of bore fluid invasion

Prediction of temperature, pressure, density, velocity distribution in H‐T‐H‐P gas wells

Determination of the formation temperature from shut-in logs: Estimation of the radius of thermal influence

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