Drilling Fluid Plays Key Role in Developing the Extreme HTHP, Elgin/Franklin Field

Fitzgerald, B.L.; McCourt, A.J.; Brangetto, Martial

doi:10.2118/59188-ms

Cited by 13 publications

(3 citation statements)

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“…With this higher water fraction the drilling fluid could adsorb larger gas influx volumes before the sag problem becomes problematic. This is likely the reason why linear paraffin based drilling fluids have had a success as a drilling fluid for high temperature and high pressure wells 23 .…”

Section: Effect Of Base Oil Viscositymentioning

confidence: 99%

Sag of Weight Materials in Oil Based Drilling Fluids

Arild¹

2002

Proceedings of IADC/SPE Asia Pacific Drilling Technology

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fax 01-972-952-9435. AbstractTo be able to keep a well under control during drilling it is important to have the weight material suspended during the whole operation. Especially in oil based, or synthetic based drilling fluids, controlling sag is difficult. A large number of wells have experienced lost circulation or well control problems with the associated high costs relating to sag. There are limited field proven methods available to predict the potential for sag for a particular drilling fluid. Therefore, barite sag continues to be one of the most difficult tasks to handle for a drilling fluid engineer. It is well known that standard viscosity readings cannot be used to predict the sag potential of a drilling fluid.The current paper discusses in detail the mechanisms of sag in oil based drilling fluid and how to treat sag. It is shown that at ultra-low shear rates the oil based drilling fluid is shear thickening as opposed to the shear thinning effect observed at higher shear rates. It is described how this shear thickening behaviour leads to sag if the drilling fluid composition is incomplete. It is described how organophilic clay should be used to minimize sag and why different types of clay have different effect onto hindering sag although none of these differences have to be visible on standard viscometer readings. Furthermore, it is suggested that "modifiers" generally have little effect on preventing sag. Different methods to monitor or predict the sag potential of drilling fluids are also outlined. Dilution of the drilling fluid normally results in increased sag. Good practice is that the dilution with new drilling fluid should be minimized to control the sag properties of the oil based drilling fluid.

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Section: Effect Of Base Oil Viscositymentioning

confidence: 99%

Sag of Weight Materials in Oil Based Drilling Fluids

Arild¹

2002

Proceedings of IADC/SPE Asia Pacific Drilling Technology

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“…For this drilling environment, under high pressures and temperatures, oil-based drilling fluids have historically been used [Caenn et al, 2014], however, the strengthening of environmental policies has directed the drilling industry towards the use of water-based fluids [Amanullah et al, 2011;Caenn et al, 2014]. Drilling in deep wells, in addition to being expensive [Fitzgerald et al, 2000], has limitations to the traditional water-based drilling fluids [Amanullah et al, 2011;Al-Yasiri and Al-Sallami, 2015], and to reverse this scenario, in the last decade, interest in the adoption of drilling nanofluids has grown [Amanullah et al, 2011;Fitzgerald et al, 2000;Perween et al, 2019;Al-Yasiri et al, 2019].…”

Section: Introductionmentioning

confidence: 99%

Rheological assessment of the interaction between hydrophobic nanoclay and xanthan gum in saline environment, for application in drilling nanofluid

Souza

Soares

Rigoli

et al. 2020

RSD

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In the last decade, exploration in high temperature and pressure wells has motivated the improvement of drilling fluids with the application of nanoparticles. In this context, nanoclay, the most available of nanoparticles, has been applied in the development of nanofluids, mainly associated with polymers. In parallel, among the polymers used, xanthan gum has been little explored for this purpose. In this work, the interaction between xanthan gum, hydrophobic nanoclay, sodium and calcium chloride and their influence on the rheological parameters of the mixture was evaluated in solution. The influence of temperature and hydration time on the rheological parameters of the mixture was also evaluated. For this purpose, nanoclay was first characterized with XRF, XRD and TGA. Then, a complete factorial design 24 was adopted, varying the concentrations of nanoclay, xanthan, sodium and calcium chlorides. Third, a Doehlert Matrix of the 7x5x3 type was adopted, varying the concentrations of nanoclay, xanthan and temperature, with the concentrations of the constant salts. In the fourth, select the effect of the hydration time on the color rheological parameters. Finally, Conductivity and Potential Zetas of sizes were verified, varying the concentration of the components and the hydration time of the mixtures. It was concluded that the interactions between the components of the mixture do not stabilize; the temperature, the salts have no significant influence on the rheology of the mixture; nanoclay in concentrations not exceeding 5% (m/v) interacts with the Minimum Shear Stress; the rheological parameters stabilize after 96h of hydration.

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“…These peculiarities are reflected in the operating cost, which ranges from £ 20 to 25 million per well, but can reach £ 40 million per well (Fitzgerald et. al., 2000).…”

Section: Introductionmentioning

confidence: 99%

Evaluation of hydrophylic montmorillonite nanofluids and xantane gum in saline environment

Souza

Soares

Rigoli

et al. 2020

RSD

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With an estimated increasing oil demand in the coming decades, the need to explore non-applicable areas is intensified, and associated with them, before the high exploration costs, the need to improve available technologies. In this sense, in the last decade, the application of nanoparticles to improve drilling fluids has been intensified. In this scenario, montmorillonite nanoclays and xanthan gums were little explored for the development of nanofluids. In this work, the influence of hydrophilic nanoclay on the rheological parameters of xanthan, sodium and calcium chlorides solutions was verified. For this, first, the clay was characterized by XRD, XRF and TGA. Then, maintaining constant the salt and xanthan concentrations, the influence of the variation in the concentration of nanoclay on the rheology of the solution was evaluated. Then, keeping the components concentrations constant, the influence of temperature was verified and then the hydration time on the rheology of the mixture. Finally, to assess the interaction of the mixture, it was verified the Electrical Conductivity and the Potential Zeta, varying the concentration of the nanoclay and the hydration time. It was concluded that: for certain nanoclay concentrations, there is an improvement in the rheology of xanthan solutions; an addition of nanoclay favors rheology in the mixture of xanthan with increased temperature; hydration time does not affect the rheology of the nanofluid; there is interaction between nanoclay and xanthan.

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Drilling Fluid Plays Key Role in Developing the Extreme HTHP, Elgin/Franklin Field

Cited by 13 publications

References 0 publications

Sag of Weight Materials in Oil Based Drilling Fluids

Sag of Weight Materials in Oil Based Drilling Fluids

Rheological assessment of the interaction between hydrophobic nanoclay and xanthan gum in saline environment, for application in drilling nanofluid

Evaluation of hydrophylic montmorillonite nanofluids and xantane gum in saline environment

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