Cuttings Transport With Oil- and Water-Based Drilling Fluids

2021 ◽  
Author(s):  
Jan David Ytrehus ◽  
Bjørnar Lund ◽  
Ali Taghipour ◽  
Arild Saasen
Keyword(s):  
Drilling Fluid ◽  
Small Diameter ◽  
Field Application ◽  
Drilling Fluids ◽  
Cuttings Transport ◽  
The North ◽  
Hydraulic Behaviour ◽  
Water Based ◽  
Similar Density ◽  
Model Fluids

Abstract Deviated well sections are common in modern well construction. In mature areas like the North Sea region, practically all producers or injector wells will have highly deviated sections. These wells must be drilled and completed in an optimal manner with respect to drill time, cost, risk and functionality. Most cuttings transport and hydraulic models are developed based on tests with model fluids and often in small diameter test sections. Hole cleaning properties and hydraulic behaviour of field fluids differ from those of most model fluids. Furthermore, results from small diameter tests may not always be relevant for, nor scalable to, field applications due to time, length and other scale differences. Hence, there is a need for studies in controlled laboratory environments with various field application designed drilling fluids to improve engineering models and practices. This paper presents results from laboratory tests using field applied fluids. The drilling fluids have similar density and viscosity within the relevant shear rate range applied during drilling operations and in the tests. One of the fluids is oil-based and the other one is an inhibitive water-based drilling fluid.

scholarly journals Wet Drilled Cuttings Bed Rheology

Energies ◽  
2021 ◽  
Vol 14 (6) ◽  
pp. 1644
Author(s):  
Camilo Pedrosa ◽  
Arild Saasen ◽  
Bjørnar Lund ◽  
Jan David Ytrehus
Keyword(s):  
Drilling Fluid ◽  
Drilling Fluids ◽  
Parallel Plates ◽  
Single Particles ◽  
Cuttings Transport ◽  
Transport Studies ◽  
Water Based ◽  
Fluid Properties ◽  
External Forces ◽  
Cuttings Bed

The cuttings transport efficiency of various drilling fluids has been studied in several approaches. This is an important aspect, since hole cleaning is often a bottleneck in well construction. The studies so far have targeted the drilling fluid cuttings’ transport capability through experiments, simulations or field data. Observed differences in the efficiency due to changes in the drilling fluid properties and compositions have been reported but not always fully understood. In this study, the cuttings bed, wetted with a single drilling fluid, was evaluated. The experiments were performed with parallel plates in an Anton Paar Physica 301 rheometer. The results showed systematic differences in the internal friction behaviors between tests of beds with oil-based and beds with water-based fluids. The observations indicated that cutting beds wetted with a polymeric water-based fluid released clusters of particles when external forces overcame the bonding forces and the beds started to break up. Similarly, it was observed that an oil-based fluid wetted bed allowed particles to break free as single particles. These findings may explain the observed differences in previous cutting transport studies.

scholarly journals OIL-BASED DRILLING FLUID'S CUTTINGS BED REMOVAL PROPERTIES FOR DEVIATED WELLBORES

2021 ◽  
pp. 1-9
Author(s):  
Jan David Ytrehus ◽  
Bjørnar Lund ◽  
Mohammad Ali Taghipour ◽  
Luca Carazza ◽  
Knud Richard Gyland ◽  
...  
Keyword(s):  
Test Section ◽  
Field Experience ◽  
Drilling Fluid ◽  
Drill String ◽  
Field Application ◽  
Viscous Fluids ◽  
Drilling Fluids ◽  
Flow Loop ◽  
Cuttings Transport ◽  
Frictional Pressure Drop

Abstract Results from cuttings transport tests in laboratory using different field applied oil-based drilling fluids with similar weight and varying viscosities are presented in this paper. The fluids are designed for highly deviated wells, and the cuttings transport performance at relevant wellbore inclinations was investigated. The experiments have been performed in a flow loop that consists of a 10 meters long test section with 50.4 mm (2″) diameter freely rotating steel drill string inside a 100 mm (≈4″) diameter wellbore made of cement. Sand particles were injected while circulating the drilling fluid through the test section. Experiments were performed at three wellbore inclinations: 48, 60 and 90 degrees from vertical. The applied flow loop dimensions are designed so that the results are scalable to field applications; especially for the 12 ¼” and 8 ½″ sections. The selected setup provides correct shear rate ranges and similar Reynolds numbers to the field application when the same fluids are applied. Results show that hole cleaning abilities of the tested fluids vary significantly with well angle, drill string rotation and flow rate. Results support field experience showing that low viscous fluids are more efficient than viscous fluids at higher flow rates and low drill string rotation. As well as per field experience more viscous fluids are efficient in combination with high drill string rotation rates. The results show the effect of cuttings transport efficiency as function of hydraulic frictional pressure drop, demonstrating methods to achieve more optimal hydraulic design in the tested conditions. The key findings have direct relevance to drilling operations.

Experimental Study of Cuttings Transport Efficiency of Water Based Drilling Fluids

2014 ◽  
Author(s):  
Jan David Ytrehus ◽  
Ali Taghipour ◽  
Bjørnar Lund ◽  
Benjamin Werner ◽  
Nils Opedal ◽  
...  
Keyword(s):  
Test Section ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Flow Loop ◽  
Cuttings Transport ◽  
Hole Cleaning ◽  
Cleaning Performance ◽  
Water Based ◽  
Fluid Properties ◽  
Drilling Cost

One important requirement for a drilling fluid is the ability to transport the cuttings out of the borehole. Improved hole cleaning is a key to solve several challenges in the drilling industry and will allow both longer wells and improved quality of well construction. It has been observed, however, that drilling fluids with similar properties according to the API standard can have significantly different behavior with respect to hole cleaning performance. The reasons for this are not fully understood. This paper presents results from laboratory tests where water based drilling fluids with similar rheological properties according to API measurements have been tested for their hole cleaning capabilities in a full scale flow loop. Thorough investigation of the viscoelastic properties of the fluids were performed with, among other instruments, a Paar-Physica rheometer. Improved understanding of the fluid properties relevant to hole cleaning performance will help develop better models of wellbore hydraulics used in planning of well operations. Eventually this may lead to higher ROP with water based drilling fluids as obtained with oil based drilling fluids. This may ease cuttings handling in many operations and thereby significantly reduce the drilling cost using (normally) more environmentally friendly fluids. The experiments have been conducted as part of an industry-sponsored research project where understanding the hole cleaning performance of various oil and water based drilling fluids is the aim. The experiments have been performed under realistic conditions. The flow loop includes a 12 meter long test section with 2″ OD freely rotating drillstring inside a 4″ ID wellbore made of concrete. Sand particles were injected while circulating the drilling fluid through the test section in horizontal position.

scholarly journals Numerical study of cutting transport using aerated drilling fluids

2021 ◽  
Vol 2119 (1) ◽  
pp. 012051
Author(s):  
V A Zhigarev ◽  
S O Zazulya ◽  
A V Minakov ◽  
A L Neverov
Keyword(s):  
Fluid Flow ◽  
Horizontal Well ◽  
Numerical Study ◽  
Drilling Fluid ◽  
Rheological Parameters ◽  
Drilling Fluids ◽  
Cuttings Transport ◽  
Foaming Agent ◽  
Water Based ◽  
Drill Pipes

Abstract The paper deals with drilling fluid flow in a horizontal well during its drilling. As part of this work, rheological parameters of water-based drilling fluid with the addition of polymers and a foaming agent were used. Cuttings transport was studied at different degrees of foam aeration. Besides, the paper presents the study of the effects of drilling fluid flow, as well as the rotation of drill pipes on the cuttings transport.

scholarly journals Development and Application of a Novel Green Water-Based Drilling Fluid

2021 ◽  
Vol 8 (1) ◽  
pp. 61-64
Author(s):  
Hongjiang Li
Keyword(s):  
Environmental Protection ◽  
Drilling Fluid ◽  
Field Application ◽  
Green Water ◽  
Drilling Fluids ◽  
Green Inhibitor ◽  
Biological Toxicity ◽  
Water Based ◽  
Green Lubricant ◽  
Filtrate Loss

In response to the technical and environmental protection requirements of water-based drilling fluids, this study independently developed a series of green supporting treatment agents for water-based drilling fluids such as the green loss reducer HB-1, green inhibitor HB-2, and green lubricant HB-3, etc., and proposed a green water-based drilling fluid system (HBDF) with good comprehensive performance. The proposed system has a heat resistance of 150°C, a HTHP (high temperature and high pressure) filtrate loss of 12 mL, a biological toxicity EC50 value greater than 105 mg/L, and a biodegradability BOD5/CODCr value of 16.2%. Now the developed HBDF system has been applied in more than 10 wells in SL oilfield, and the field application results show that the proposed HBDF system has stable rheological and filtrate loss performance, good anti-pollution ability, and easy and simple maintenance operations; after drilling, the biological toxicity of the drilling fluids can meet the environmental protection requirements, which has provided a technical reference for the research of green drilling fluids and the green development of SL Oilfield.

Drilling Fluid’s Cuttings Bed Removal Properties for Deviated Wellbores

2020 ◽  
Author(s):  
Jan David Ytrehus ◽  
Bjørnar Lund ◽  
Ali Taghipour ◽  
Luca Carazza ◽  
Knud Richard Gyland ◽  
...  
Keyword(s):  
Test Section ◽  
Field Experience ◽  
Drilling Fluid ◽  
Drill String ◽  
Field Application ◽  
Viscous Fluids ◽  
Drilling Fluids ◽  
Flow Loop ◽  
Cuttings Transport ◽  
Frictional Pressure Drop

Abstract Results from cuttings transport tests in laboratory using different field applied oil-based drilling fluids with similar weight and varying viscosities are presented in this paper. The fluids are designed for highly deviated wells, and the cuttings transport performance at relevant wellbore inclinations was investigated. The experiments have been performed in a flow loop that consists of a 10 meters long test section with 2″ OD freely rotating steel drill string inside a 4″ ID wellbore made of cement. Sand particles were injected while circulating the drilling fluid through the test section. Experiments were performed at three wellbore inclinations: 48, 60 and 90 degrees from vertical. The applied flow loop dimensions are designed so that the results are scalable to field applications; especially for the 12,25″ and 8,5″ sections. The selected setup provides correct shear rate ranges and equal Reynolds number to the field application when the same fluids are applied. Results show that hole cleaning abilities of the tested fluids vary significantly with well angle, drill string rotation and flow rate. Results support field experience showing that low viscous fluids are more efficient than viscous at higher flow rates and low drill string rotation. As well as per field experience more viscous fluids are efficient in combination with high drill string rotation rates. The results show the effect of cuttings transport efficiency as function of hydraulic frictional pressure drop, demonstrating methods to achieve more optimal hydraulic design in the tested conditions. The key findings have direct relevance to drilling operations.

Quantification of Multiple Factors and Interaction Effects on Drilling Fluid Invasion

2018 ◽  
Author(s):  
Chinedum Peter Ezeakacha ◽  
Saeed Salehi ◽  
Raj Kiran
Keyword(s):  
Porous Media ◽  
Drilling Fluid ◽  
Field Application ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Multiple Factors ◽  
Test Conditions ◽  
Water Based ◽  
Rotary Speed ◽  
Temperature Interaction

Water-based drilling mud is one of the commonly used fluid systems for drilling operations. The loss of drilling fluid in porous media and fractured formations have been one of the industry’s focus in the past decades. However, the dynamics and constantly changing wellbore conditions push the boundaries for more research into accurate quantification and mitigation methods for fluid loss. In the design and development of drilling fluids, most test conditions are kept constant during fluids property testing. Drilling fluid loss and rheological parameters are determined experimentally at constant test conditions, and according to the combination of mud additives, rather than a comprehensive approach. In addition, conventional methods of quantifying drilling fluid loss properties for field application can be is time-consuming, considering that multiple factors impact fluid loss. This study presents a statistical engineering approach for pore-scale characterization of water-based mud (WBM) invasion. The methods used in this research are: special case of factorial design of experiment (DoE), analysis of variance (ANOVA), and regression. Important field parameters based on previous studies and industry recommendations were carefully integrated in the DoE and result analyses. These parameters include but not limited to: porous media type, temperature, type of lost circulation material (LCM), concentration of LCM, drilling string rotary speed, and eccentricity. Ceramic filter tubes were used for the first set of experiments and Upper Grey sandstone rock samples were used for the second set of experiments. The statistical analyses performed in this study were based on a 95% confidence interval (CI). The results show that for single factor interpretation, increase in temperature and rotary speed increased dynamic fluid invasion significantly. Increase in LCM concentration resulted to a significant decrease in fluid invasion. LCM concentration and rotary speed interaction revealed a significant decrease in fluid invasion. LCM concentration and temperature interaction significantly increased fluid invasion. Rotary speed and temperature interaction also increased fluid invasion significantly. The three-factor interaction effect of LCM concentration, rotary speed, and temperature was not significant in reducing fluid invasion. For the conditions used in this study, the regression analysis showed that dynamic fluid invasion in Upper Grey sandstone can be explained from variation in LCM concentration and rotary speed. The results and methods from this study can provide reliable information for drilling fluids design and selecting operating conditions for field application.

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.

A Generalized Model for the Field Assessment of Drilling Fluid Viscoelasticity

2021 ◽  
Author(s):  
Chen Hongbo ◽  
Okesanya Temi ◽  
Kuru Ergun ◽  
Heath Garett ◽  
Hadley Dylan
Keyword(s):  
Drilling Fluid ◽  
Field Testing ◽  
Field Application ◽  
Testing Equipment ◽  
Drilling Fluids ◽  
Rotational Viscometer ◽  
Generalized Model ◽  
Fluid Elasticity ◽  
Field Samples ◽  
Drilling Operations

Abstract Recent studies highlight the significant role of drilling fluid elasticity in particle suspension and hole cleaning during drilling operations. Traditional methods to quantify fluid elasticity require the use of advanced rheometers not suitable for field application. The main objectives of the study were to develop a generalized model for determining viscoelasticity of a drilling fluid using standard field-testing equipment, investigate the factors influencing drilling fluid viscoelasticity in the field, and provide an understanding of the viscoelasticity concept. Over 80 fluid formulations used in this study included field samples of oil-based drilling fluids as well as laboratory samples formulated with bentonite and other polymers such as partially-hydrolyzed polyacrylamide, synthesized xanthan gum, and polyacrylic acid. Detailed rheological characterizations of these fluids used a funnel viscometer and a rotational viscometer. Elastic properties of the drilling fluids (quantified in terms of the energy required to cause an irreversible deformation in the fluid's structure) were obtained from oscillatory tests conducted using a cone-and-plate type rheometer. Using an empirical approach, a non-iterative model for quantifying elasticity correlated test results from a funnel viscometer and a rotational viscometer. The generalized model was able to predict the elasticity of drilling fluids with a mean absolute error of 5.75%. In addition, the model offers practical versatility by requiring only standard drilling fluid testing equipment to predict viscoelasticity. Experimental results showed that non-aqueous fluid (NAF) viscoelasticity is inversely proportional to the oil-water ratio and the presence of clay greatly debilitates the elasticity of the samples while enhancing their viscosity. The work efforts present a model for estimating drilling fluid elasticity using standard drilling fluid field-testing equipment. Furthermore, a revised approach helps to describe the viscoelastic property of a fluid that involves quantifying the amount of energy required to irreversibly deform a unit volume of viscoelastic fluid. The methodology, combined with the explanation of the viscoelasticity concept, provides a practical tool for optimizing drilling operations based on the viscoelasticity of drilling fluids.

ENVIRONMENTAL DRILLING SOLUTIONS ON THE POLYMERIC BASIS

2020 ◽  
Author(s):  
E.A. Flik ◽  
◽  
Y.E. Kolodyazhnaya
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Oil And Gas Industry ◽  
Environmental Safety ◽  
Drilling Fluids ◽  
Gas Industry ◽  
Fluid Systems ◽  
Water Based

The article assesses the environmental safety of drilling fluids that are currently widely used in the oil and gas industry. It shows active development of water-based drilling fluid systems using xanthan biopolymer.

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