Annular Frictional Pressure Losses During Drilling: The Effect of Drillstring Rotation

2013 ◽  
Author(s):  
Arild Saasen
Keyword(s):  
Rheological Properties ◽  
Pressure Loss ◽  
Drilling Fluid ◽  
Axial Flow ◽  
Drilling Fluids ◽  
Unstable Flow ◽  
Pressure Losses ◽  
Shear Dependent Viscosity ◽  
Water Based ◽  
Dependent Viscosity

Controlling the annular frictional pressure losses is important in order to drill safely with overpressure without fracturing the formation. To predict these pressure losses, however, is not straightforward. First of all, the pressure losses depend on the annulus eccentricity. Moving the drillstring to the wall generates a wider flow channel in part of the annulus reducing the frictional pressure losses significantly. The drillstring motion itself also affects the pressure loss significantly. The drillstring rotation, even for fairly small rotation rates, creates unstable flow and sometimes turbulence in the annulus even without axial flow. Transversal motion of the drillstring creates vortices that de-stabilize the flow. Consequently, the annular frictional pressure loss is increased even though the drilling fluid becomes thinner because of added shear rate. Naturally, the rheological properties of the drilling fluid play an important role. These rheological properties include more properties than the viscosity as measured by API procedures. It is impossible to use the same frictional pressure loss model for water based and oil based drilling fluids even if their viscosity profile is equal because of the different ways these fluids build viscosity. Water based drilling fluids are normally constructed as a polymer solution while the oil based are combinations of emulsions and dispersions. Furthermore, within both water based and oil based drilling fluids there are functional differences. These differences may be sufficiently large to require different models for two water based drilling fluids built with different types of polymers. In addition to these phenomena washouts and tool joints will create localised pressure losses. These localised pressure losses will again be coupled with the rheological properties of the drilling fluids. In the paper, all the above mentioned different phenomena and their consequences for annular pressure losses will be discussed in detail. Application of Det norske field data will be used as an example. The data cannot be used to build general models. The arguments for this model restriction are based on flow stability analysis and the consequences of using drilling fluids with different rheological properties. These different rheological properties include shear dependent viscosity, elongational viscosity and other viscoelastic properties.

Annular Frictional Pressure Losses During Drilling—Predicting the Effect of Drillstring Rotation

2014 ◽  
Vol 136 (3) ◽  
Author(s):  
Arild Saasen
Keyword(s):  
Rheological Properties ◽  
Pressure Loss ◽  
Drilling Fluid ◽  
Axial Flow ◽  
Drilling Fluids ◽  
Unstable Flow ◽  
Pressure Losses ◽  
Shear Dependent Viscosity ◽  
Water Based ◽  
Dependent Viscosity

Controlling the annular frictional pressure losses is important in order to drill safely with overpressure without fracturing the formation. To predict these pressure losses, however, is not straightforward. First of all, the pressure losses depend on the annulus eccentricity. Moving the drillstring to the wall generates a wider flow channel in part of the annulus which reduces the frictional pressure losses significantly. The drillstring motion itself also affects the pressure loss significantly. The drillstring rotation, even for fairly small rotation rates, creates unstable flow and sometimes turbulence in the annulus even without axial flow. Transversal motion of the drillstring creates vortices that destabilize the flow. Consequently, the annular frictional pressure loss is increased even though the drilling fluid becomes thinner because of added shear rate. Naturally, the rheological properties of the drilling fluid play an important role. These rheological properties include more properties than the viscosity as measured by API procedures. It is impossible to use the same frictional pressure loss model for water based and oil based drilling fluids even if their viscosity profile is equal because of the different ways these fluids build viscosity. Water based drilling fluids are normally constructed as a polymer solution while the oil based are combinations of emulsions and dispersions. Furthermore, within both water based and oil based drilling fluids there are functional differences. These differences may be sufficiently large to require different models for two water based drilling fluids built with different types of polymers. In addition to these phenomena washouts and tool joints will create localised pressure losses. These localised pressure losses will again be coupled with the rheological properties of the drilling fluids. In this paper, all the above mentioned phenomena and their consequences for annular pressure losses will be discussed in detail. North Sea field data is used as an example. It is not straightforward to build general annular pressure loss models. This argument is based on flow stability analysis and the consequences of using drilling fluids with different rheological properties. These different rheological properties include shear dependent viscosity, elongational viscosity and other viscoelastic properties.

Method and Mechanism of Regulating Rheological Properties of Water-Based Drilling Fluid by High-Frequency and High-Voltage Alternating Current Electric Field

SPE Journal ◽  
2020 ◽  
Vol 25 (05) ◽  
pp. 2220-2233
Author(s):  
Weian Huang ◽  
Ming Lei ◽  
Jingwen Wang ◽  
Kaihe Lv ◽  
Lin Jiang ◽  
...  
Keyword(s):  
Electric Field ◽  
Rheological Properties ◽  
High Voltage ◽  
High Frequency ◽  
Pulse Width ◽  
Drilling Fluid ◽  
Width Ratio ◽  
Drilling Fluids ◽  
Water Based ◽  
Bentonite Suspension

Summary The rheology of drilling fluid is commonly regulated by chemical methods. In this work, a physical method of a high-frequency and high-voltage alternating current (AC) electric field to regulate the rheological properties of water-based drilling fluid is established. The effects of the electric field on the continuous phase and dispersed phase, as well as two kinds of water-based drilling fluids, were investigated, and the response relationship among rheological properties modeled by Bingham and Herschel-Bulkley (H-B) models and electric-field parameters was explored. Results showed that water conductivity increased when voltage reached 4 kV, whereas it was restored to the original state after 3 hours in the absence of an electric field, showing a memory effect. The effect was also observed on bentonite suspension, whose plastic viscosity increased with the aid of an electric field and decreased over time. Voltage showed the greatest effect on bentonite-suspension viscosity, followed by frequency and pulse-width ratio. Under the condition of voltage of 5 kV, frequency of 5 kHz, and pulse-width ratio of 80%, there was a maximum increase of 50% in viscosity. The addition of salts caused bentonite-suspension flocculation, and electric field reduced the consistency coefficient and relieved flocculation state. When polymers were incorporated in bentonite suspension, the electric field could decrease the adsorption amount between clay particles and polymeric additives such as amphoteric and acrylamide-based polymers. For two typical drilling fluids, the voltage of an introduced electric field was the main controlling factor to change the rheological properties; their plastic viscosity and consistency coefficient both started to increase when voltage reached 4 kV.

Rheological Properties of Barite Sediments in Water-Based Drilling Fluids

2018 ◽  
Author(s):  
Torbjørn Vrålstad ◽  
Ragnhild Skorpa ◽  
Arild Saasen
Keyword(s):  
Rheological Properties ◽  
Drilling Fluid ◽  
Gravity Separation ◽  
Drilling Fluids ◽  
Water Based ◽  
Different Types ◽  
Preliminary Study ◽  
Well Abandonment

When a drilling fluid column remains static over a timeframe of several years, the drilling fluid separates into different sediment phases due to gravity separation. These heavy sediments, entitled “settled barite”, are the cause of significant operational problems several years after drilling. An important problem caused by settled barite occurs when performing casing cut-and-pull operations during slot recovery and well abandonment: the casing is “stuck” due to the sediments in the annulus outside the casing. The consistency and rheological properties of the sediments determine how easily the casing is removed. In this paper, we report a preliminary study were we have artificially prepared gravity sediment phases for two different types of water-based drilling fluids; one KCl/polymer-based fluid and one bentonite-based fluid. By studying the rheological properties of the obtained sediment phases, we see that there are considerable differences between the sediments for these different drilling fluids.

Effect of Drillstring Deflection and Rotary Speed on Annular Frictional Pressure Losses

2013 ◽  
Author(s):  
Oney Erge ◽  
Mehmet E. Ozbayoglu ◽  
Stefan Z. Miska ◽  
Mengjiao Yu ◽  
Nicholas Takach ◽  
...  
Keyword(s):  
Pressure Loss ◽  
Drilling Fluid ◽  
Flow Behavior ◽  
Hole Drilling ◽  
Accurate Estimation ◽  
Drilling Fluids ◽  
Limited Information ◽  
Pressure Losses ◽  
Gas Drilling ◽  
Fracture Pressure

Keeping the drilling fluid equivalent circulating density in the operating window between the pore and fracture pressure is a challenge, particularly when the gap between these two is narrow, such as in offshore applications. To overcome this challenge, accurate estimation of frictional pressure loss in the annulus is essential, especially for multilateral, extended reach and slim hole drilling applications usually encountered in shale gas and/or oil drilling. A better estimation of frictional pressure losses will provide improved well control, optimized bit hydraulics, a better drilling fluid program and pump selection. Field and experimental measurements showed that pressure loss in the annulus is strongly affected by the pipe rotation and eccentricity. Eccentricity will not be constant throughout a wellbore, especially in highly inclined and horizontal sections. In an actual wellbore, because of rotation speed and the applied weight, some portion of the drillstring will undergo compression. As a result, variable eccentricity will be encountered. At high compression, the drillstring will buckle, resulting in sinusoidal or helical buckling configurations. Most of the drilling fluids used today show highly non-Newtonian flow behavior, which can be characterized using the Yield Power Law (YPL). Nevertheless, in the literature, there is limited information and research on YPL fluids flowing through annular geometries with the inner pipe buckled, rotating, and eccentric. Furthermore, there are discrepancies reported between the estimated and measured frictional pressure losses with or without drillstring rotation of YPL fluids, even when the inner pipe is straight. The major focus of this project is on a horizontal well setup with drillstring under compression, considering the influence of rotation on frictional pressure losses of YPL fluids. The test matrix includes flow through the annulus for various buckling modes with and without rotation of the inner pipe. Sinusoidal, helical and transition from sinusoidal to helical configurations with and without the rotation of the drillstring are investigated. Results show a substantial difference of frictional pressure losses between the non-compressed and compressed drillstring. The drilling industry has recently been involved in incidents that show the need for critical improvements for evaluating and avoiding risks in oil/gas drilling. The information obtained from this study can be used to improve the control of bottomhole pressures during extended reach, horizontal, managed pressure, offshore and slim hole drilling applications. This will lead to safer and enhanced optimization of drilling operations.

scholarly journals Annular frictional pressure losses for drilling fluids

2020 ◽  
pp. 1-19
Author(s):  
Arild Saasen ◽  
Jan David Ytrehus ◽  
Bjørnar Lund
Keyword(s):  
Pressure Loss ◽  
Parallel Plate ◽  
Fluid Model ◽  
Axial Flow ◽  
Measured Data ◽  
Drilling Fluids ◽  
Laboratory Measurements ◽  
Model Approximation ◽  
Pressure Losses ◽  
Shear Rates

Abstract In the paper it is demonstrated how a Herschel-Bulkley fluid model, where the parameters are selected from relevant shear rate range of the flow and are parametrically independent, can be used for pressure loss calculations. The model is found to provide adequate pressure loss predictions for axial flow in an annulus where the inner cylinder does not rotate. It is described how one can simplify a slot model approximation of the annulus pressure loss using the Herschel-Bulkley fluid model (Founargiotakis model). This simplified model gives approximately the same accuracy as does the full Founargiotakis model. It is shown that use of such a parallel plate model gives reasonably good fit to measured data on laminar flow of oil-based drilling fluids if the viscous data are measured at relevant shear rates for the flow. Laboratory measurements indicate that use of the simplified pressure loss model is also valid for turbulent flow. However, the predictions should be adjusted for the surface roughness in the well.

scholarly journals Plum Tree Gums as Local Alternatives for Foreign Drilling Fluid Materials

2021 ◽  
Vol 7 (3) ◽  
pp. 51-65
Author(s):  
Dr. Faleh H. M. Almahdawi ◽  
Dr. Mohammad N. Hussain ◽  
Haider Salim Jasim
Keyword(s):  
Rheological Properties ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Local Alternatives ◽  
Oil Well ◽  
Well Drilling ◽  
Local Alternative ◽  
Water Based ◽  
Drilling Cost ◽  
Plum Tree

A few years ago oil well drilling cost increased due to using modern technique such as equipment   and materials that are used by specialist companies so studies and researches were required to decrease these costs. In this study we tried to find local alternatives for foreign drilling fluid materials that are aimed to decrease oil well drilling cost although the cost of drilling fluid materials reach to 30 % of total materials cost of drilling oil well.       In the first part of this study seven local materials and it's tested under API Specification 13A for Drilling Fluids Materials were investigated. Plum Tree Gum was succeeded in this test among several other materials as drilling fluid materials. The second part of this study was a comparison between these local alternative and similar foreign materials for same sample to show physical and rheological properties. The third part of this study was tested this local alternative under different values temperature to show effect the temperature on physical and rheological properties of this local alternative. The results approved that; Plum Tree Gum, local alternative, can use as filtration control materials for water based drilling fluid. Also this local alternative increased viscosity as minimal for water based drilling fluids, So it can be used as part alternative for Bentonite to increase viscosity by increasing Yield point and decreasing solids concentration in drilling fluids so it has  positive effect on Rig equipment’s and Pay-zone.   Plum Tree Gum is Ore polymers (plant origin)  

An Experimental Investigation of Temperature and Aging Effects on Bentonite and Sepiolite Drilling Fluids

2018 ◽  
Author(s):  
Tariq Ahmed ◽  
Nura Makwashi
Keyword(s):  
Rheological Properties ◽  
Yield Point ◽  
Xanthan Gum ◽  
Ageing Time ◽  
Drilling Fluid ◽  
Gel Strength ◽  
Plastic Viscosity ◽  
Drilling Fluids ◽  
Aging Effects ◽  
Water Based

The selection and control of a suitable drilling fluid is necessary to successfully drill an oil and gas well. The rheological properties of drilling fluids vary with changes in conditions such as time and temperature. Slight changes in these conditions can cause unpredictable and significant changes in the mud’s properties. This makes it necessary to study the rheology of drilling fluids and how it is affected by these changes. At the rig sites, tests are carried out by the mud engineers to ensure that the properties of the drilling fluids are within the required limits. Similar tests were carried out at the laboratory in this work to determine the plastic viscosity, yield point, gel strength of mud samples at different conditions of ageing time, temperature and concentration of Xanthan gum (X.G) used as an additive. The Experiments carried out were grouped into three. The first was done with the aim to further explain how the Bentonite and Sepiolite water-based drilling fluids behaves after been aged for certain period. The second sets of experiments were conducted to investigate how the rheological properties of water-based Bentonite muds are affected by different concentration of xanthan gum added as an additive to improve the muds properties and the last sets of experiments were done to investigate the ageing effect on Bentonite mud treated with 250mg/L xanthan gum. Effects of temperature were also considered in these experiments with a 10℃ variation in the first group and 20℃ in the other two groups between readings from 20℃ to 60℃ . Results obtained indicated that Sepiolite water-based drilling fluid offers better plastic viscosity and yield point as compared to Bentonite water-based drilling fluids. It was also found that the viscosity and yield point of Sepiolite, Bentonite and treated Bentonite muds decreases with increase ageing time and temperature while the gel strength increases with ageing time but similarly decreases with increase in temperature. In the second group, results obtained indicated that plastic viscosity, yield point and gel strength increases as concentration of xanthan gum increases, all of which decreases with increase in temperature.

scholarly journals Comparison between the Effect of Local Katira Gum and Xanthan Gum on the Rheological Properties of Water-based Drilling Fluids

2020 ◽  
Vol 4 (2) ◽  
pp. 18
Author(s):  
Bayan Qadir Sofy Hussein ◽  
Khalid Mahmood Ismael Sharbazheri ◽  
Nabil Adiel Tayeb Ubaid
Keyword(s):  
Rheological Property ◽  
Rheological Properties ◽  
Yield Point ◽  
Experimental Work ◽  
Apparent Viscosity ◽  
Xanthan Gum ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Drilling Mud ◽  
Water Based

The rheological properties of drilling fluids have an important role in providing a stable wellbore and eliminating the borehole problems. Several materials including polymers (xanthan gum) can be used to improve these properties. In this study, the effect of the local Katira, as a new polymer, on the rheological properties of the drilling fluids prepared as the bentonite-water-based mud has been investigated in comparison with the conventional xanthan gum. Experimental work was done to study of rheological properties of several gums such as, local katira gum, and xanthan gum bentonite drilling mud. Different samples of drilling fluids are prepared adding the xanthan gum and local katira to the base drilling fluid at different concentrations using Hamilton Beach mixer. The prepared samples are passed through rheological property tests including the apparent viscosity, plastic viscosity, and yield point (YP) under different temperature conditions. The obtained results show that the viscosity is increased from 5 to 8.5 cp and YP is increased from 18.5 to 30.5 lb/100 ft2, with increasing the concentration of the xanthan gum from 0.1 to 0.4. However, the effect of the local katira in increasing the viscosity and YP is lower compared with the xanthan gum, which are ranged between 5–6 cp and 18.5–20.5 cp.

Rheological Properties of Water-Based Drilling Fluids in Deep Offshore Conditions

2019 ◽  
Author(s):  
Qian Ding ◽  
Baojiang Sun ◽  
Zhiyuan Wang ◽  
Yonghai Gao ◽  
Yu Gao ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Low Temperature ◽  
Rheological Properties ◽  
Apparent Viscosity ◽  
Drilling Fluid ◽  
Plastic Viscosity ◽  
Drilling Fluids ◽  
Water Based ◽  
Temperature And Pressure

Abstract In deep-water drilling, the drilling fluid is affected by the alternating temperature field derived from the low temperature of the seawater and the high temperature of the formation. The complicated wellbore temperature and pressure environments make the prediction of rheological properties of the drilling fluid difficult. In this study, the rheological properties of water-based drilling fluid in full temperature and pressure range of deep-water conditions were tested from 2 to 150 °C (35.6 to 302 °F) and 0.1 to 70 MPa (14.5 to 10000psi). The experiment was carried out by the OFI130-77 high temperature and high pressure rheometer. The experimental data were processed by multiple regression analysis method, and the mathematical model for predicting the apparent viscosity, plastic viscosity and yield point of water-based drilling fluid under high temperature and high pressure conditions was established. The experimental results show that when the temperature is lower than 65 °C (149 °F), the apparent viscosity and plastic viscosity of the water-based drilling fluid decrease significantly with increasing temperature. When the temperature is higher than 65 °C (149 °F), the apparent viscosity and plastic viscosity decrease slowly. Under low temperature conditions, the effect of pressure on the apparent viscosity and plastic viscosity of water-based drilling fluids is relatively significant. The calculated values of the prediction model have a good agreement with the experimental measurements. Compared with the traditional model, this prediction model has a significant improvement in the prediction accuracy in the low temperature section, which can provide a calculation basis for on-site application of deepwater drilling fluid.

Effect of Ferric Oxide and Magnesium Oxide Nanoparticles on Iraqi Bentonite Performance in Water Based Drilling Fluid

2020 ◽  
Vol 27 (2) ◽  
pp. 14-23
Author(s):  
Ghofran F. Al-Ghanimi ◽  
Nada S. Al-Zubaidi
Keyword(s):  
Rheological Properties ◽  
Ferric Oxide ◽  
Drilling Fluid ◽  
Oil And Gas Industry ◽  
Nano Particles ◽  
Western Desert ◽  
Oxide Nanoparticles ◽  
Drilling Fluids ◽  
Water Based ◽  
The Impact

In oil and gas industry, the nanotechnology has been applied in different fields. Reservoir, exploration, drilling, completion, production, processing, and refinery are nanotechnology applications fields. Nanoparticles materials are one of the areas that are utilized in preparing drilling fluids. These nanomaterials are used to formulate high performance drilling fluids. In other words, these nano particles materials can be used to design smart drilling fluids. The properties of these drilling fluids can be met the well conditions requirements. The aim of this study is to enhance the performance of Iraqi bentonite in drilling fluids using nanomaterials. Iraqi calcium montmorillonite clay (Ca- bentonite) from Wadi Bashera in Iraqi Western Desert was obtained and studied in order to use it as an alternative active solid to the imported commercial bentonite. Water based drilling fluids were prepared with 3, 6, and 12 wt. % of Iraqi bentonite. Mgnesium oxide nanoparticles (MgO NPs) and ferric oxide nanoparticles (Fe2O3 NPs) with different concentrations were used. The experimental work showed that, MgO NPs resulted in a significant increase in the rheological properties of drilling fluids prepared with 3 and 6 wt. % of Iraqi bentonite. In contrast,  moderate effect on the rheological properties of drilling fluid prepared with 12 wt. % of Iraqi bentonite were obtained with low concentrations of Fe2O3 NPs. Basically drilling fluids prepared with Iraqi bentonite had extreme filtrate volume compared with API specifications and poor controlling to filtration properties were obtained with MgO NPs and Fe2O3 NPs additions. The impact of these two nanomaterials was revealed on the stability of drilling fluids prepared with Iraqi bentonite, where an enhancemment from 65 % to 100% was observed.

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