Effect of Temperature and Pressure on the Density of Drilling Fluids

McMordie, W.C.; Bland, R.G.; Häuser, J.

doi:10.2118/11114-ms

Cited by 54 publications

(16 citation statements)

References 2 publications

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“…PVT data showed that the density of oils varies inversely with temperature and directly with pressure. McMordie et al (1982) analyzed the density change of oil-and water-based drilling fluids. Their study concluded that change in density of drilling fluids because of downhole conditions is independent of initial densities of the drilling fluid and depends mainly on the base oil of the emulsion system.…”

Section: Introductionmentioning

confidence: 99%

Olefin-Based Synthetic-Drilling-Fluids Volumetric Behavior Under Downhole Conditions

Demirdal¹,

Cunha

2009

SPE Drilling &Amp; Completion

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Usual practice in drilling engineering is to determine drilling-fluid density at surface conditions assuming that drilling-fluid density does not change with changing downhole conditions. This assumption may result in inaccuracy while estimating static and dynamic pressures in the wellbore, especially when synthetic-based drilling fluids are used. Inaccurate estimation of the pressure profile in the annulus can lead to severe well problems such as kicks, drilling-fluid losses, and wellbore instability. In addition, inaccurate pressure-profile estimation can affect the success of managed-pressure-drilling (MPD) operations, which require real-time knowledge of wellbore pressures to keep wellbore pressure between formation pore and fracture pressures using a control choke placed on the return line of the annulus.Effects of pressure and temperature on volumetric behavior of two olefin-based synthetic oils are investigated in this study using a mercury-free pressure/volume/temperature (PVT) system. The olefin-based synthetic oils used in this study are C16C18 internal olefin (IO) and C12C14 linear alpha olefin (LAO). To simulate deep offshore situations, the temperature is ranged between 25 and 175°C, while the pressure is ranged between 0 and 14,000 psig.In addition, volumetric performances of olefin-based syntheticoil systems under investigation are compared with those of water, brine solution, mineral oil, diesel oil, and n-paraffin-based oil under similar conditions.The study shows that the volumetric properties of syntheticbased oils are more sensitive to pressure and temperature conditions compared to water, brine solutions, mineral oil, and diesel oil. Once emulsion systems containing synthetic-based oils are used, density change with respect to downhole conditions should be modeled to increase the reliability of pressure-profile calculations.

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Section: Introductionmentioning

confidence: 99%

Olefin-Based Synthetic-Drilling-Fluids Volumetric Behavior Under Downhole Conditions

Demirdal¹,

Cunha

2009

SPE Drilling &Amp; Completion

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“…4 investigated the effects of pressure and temperature on the densities of water-and diesel-oil-based muds. Hoberock et at.…”

Section: Introductionmentioning

confidence: 99%

A Model for Predicting the Density of Oil-Based Muds at High Pressures and Temperatures

Peters¹,

Chenevert²,

Zhang³

1990

SPE Drilling Engineering

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A compositional material-balance model was used to predict the densities of diesel-and mineral-oil-based muds at elevated pressures and temperatures. We measured the densities of diesel oil, two mineral oils, and calcium chloride solutions from 78 to 350°F and from 0 to 15,000 psig. The measured densities were used in an existing compositional material-balance model to predict the densities of 11-and 17-lbm/gal oil-based muds. We also measured the densities of these muds at elevated pressures and temperatures and compared them with the predicted values. The results show excellent agreement between measured and predicted densities. The experimental density data were used to predict downhole densities and static wellbore pressures for the oil-based muds. Results show that the mineral-oil muds are not only more compressible than the diesel-oil muds, but also more susceptible to thermal expansion. Therefore, all the oil-based muds tend to give essentially the same static-wellbore-pressure profile.

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“…As property per content in the drilling fluid performs different features with a variety of temperatures and pressures, the properties of each drilling fluid are different. McMordie [11] logged the density of water-based and oil-based drilling fluid under the conditions of 70-400 • F and 0-14,000 psig. Hoberock [12] provided the density prediction model of water-based and oil-based drilling fluid based on the mass balance.…”

Section: Introductionmentioning

confidence: 99%

Equivalent Circulation Density Analysis of Geothermal Well by Coupling Temperature

et al. 2017

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Abstract:The accurate control of the wellbore pressure not only prevents lost circulation/blowout and fracturing formation by managing the density of the drilling fluid, but also improves productivity by mitigating reservoir damage. Calculating the geothermal pressure of a geothermal well by constant parameters would easily bring big errors, as the changes of physical, rheological and thermal properties of drilling fluids with temperature are neglected. This paper researched the wellbore pressure coupling by calculating the temperature distribution with the existing model, fitting the rule of density of the drilling fluid with the temperature and establishing mathematical models to simulate the wellbore pressures, which are expressed as the variation of Equivalent Circulating Density (ECD) under different conditions. With this method, the temperature and ECDs in the wellbore of the first medium-deep geothermal well, ZK212 Yangyi Geothermal Field in Tibet, were determined, and the sensitivity analysis was simulated by assumed parameters, i.e., the circulating time, flow rate, geothermal gradient, diameters of the wellbore, rheological models and regimes. The results indicated that the geothermal gradient and flow rate were the most influential parameters on the temperature and ECD distribution, and additives added in the drilling fluid should be added carefully as they change the properties of the drilling fluid and induce the redistribution of temperature. To ensure the safe drilling and velocity of pipes tripping into the hole, the depth and diameter of the wellbore are considered to control the surge pressure.

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Effect of Temperature and Pressure on the Density of Drilling Fluids

Cited by 54 publications

References 2 publications

Olefin-Based Synthetic-Drilling-Fluids Volumetric Behavior Under Downhole Conditions

Olefin-Based Synthetic-Drilling-Fluids Volumetric Behavior Under Downhole Conditions

A Model for Predicting the Density of Oil-Based Muds at High Pressures and Temperatures

Equivalent Circulation Density Analysis of Geothermal Well by Coupling Temperature

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