scholarly journals H2S Scavenging Capacity and Rheological Properties of Water-Based Drilling Muds

ACS Omega ◽  
2020 ◽  
Vol 5 (47) ◽  
pp. 30729-30739
Author(s):  
Sagheer A. Onaizi ◽  
Monaf Abdalmajid Gawish ◽  
Mobeen Murtaza ◽  
Ibrahim Gomaa ◽  
Zeeshan Tariq ◽  
...  
Keyword(s):  
Rheological Properties ◽  
Scavenging Capacity ◽  
Water Based ◽  
Drilling Muds

scholarly journals Comparative Analysis of the Effect of Barite and Hematite on the Rheology of Water-Based Drilling Mud

2021 ◽  
Vol 1 (2) ◽  
Author(s):  
Osei H
Keyword(s):  
Rheological Properties ◽  
Drilling Fluid ◽  
Attrition Rate ◽  
Drilling Mud ◽  
Cleaning Efficiency ◽  
Drilling Operation ◽  
Water Based ◽  
Petroleum Resources ◽  
Drilling Muds ◽  
The Impact

High demand for oil and gas has led to exploration of more petroleum resources even at remote areas. The petroleum resources are found in deeper subsurface formations and drilling into such formations requires a well-designed drilling mud with suitable rheological properties in order to avoid or reduce associated drilling problems. This is because rheological properties of drilling muds have considerable effect on the drilling operation and cleaning of the wellbore. Mud engineers therefore use mud additives to influence the properties and functions of the drilling fluid to obtain the desired drilling mud properties especially rheological properties. This study investigated and compared the impact of barite and hematite as weighting agents for water-based drilling muds and their influence on the rheology. Water-based muds of different concentrations of weighting agents (5%, 10%, 15% and 20% of the total weight of the drilling mud) were prepared and their rheological properties determined at an ambient temperature of 24ᵒC to check their impact on drilling operation. The results found hematite to produce higher mud density, plastic viscosity, gel strength and yield point when compared to barite at the same weighting concentrations. The higher performance of the hematite-based muds might be attributed to it having higher specific gravity, better particle distribution and lower particle attrition rate and more importantly being free from contaminants. The water-based muds with hematite will therefore be more promising drilling muds with higher drilling and hole cleaning efficiency than those having barite.

Complications in the drilling of wells projected to VIII horizon of Bulla-deniz field and the measures towards their elimination

2020 ◽  
pp. 15-19
Author(s):  
R.M. Zeinalov ◽  
◽  
E.A. Kazimov ◽  
Keyword(s):  
Rheological Properties ◽  
Clay Rock ◽  
Drilling Mud ◽  
Round Trip ◽  
Water Based ◽  
Drilling Muds

The paper reviews the main reasons for the failures and complications with further specific recommendations for completing the well to the project depth in Bulla-deniz field. The practicability of the application of water-based drilling muds characterized with the wall-plastering and managed structural-rheological properties instead of the hydrocarbon-based drilling mud to the 2700 m. It is recommended to use hydrocarbon-based drilling mud only in the revelation of production horizon via drilling. Regardless of the drilling mud’s type and properties, the time of the tool remaining stationary while drilling and round trip operations should not exceed 3-5 minutes. In order to avoid the loss of the drilling mud into the formation, the casing of production string in consolidated clay rock is recommended.

scholarly journals Comparative Study of Biopolymers Action on Physico-Chemical and Rheological Properties of Water-Based Drilling Muds

2014 ◽  
Vol 26 (14) ◽  
pp. 4386-4390 ◽  
Author(s):  
Abdelhak Bentriou ◽  
Karim Fourar ◽  
Abdelbaki Benmounah ◽  
Bahim Safi
Keyword(s):  
Comparative Study ◽  
Rheological Properties ◽  
Physico Chemical ◽  
Water Based ◽  
Drilling Muds

scholarly journals Investigation of regulating rheological properties of water-based drilling fluids by ultrasound

2021 ◽  
Author(s):  
Wei-An Huang ◽  
Jing-Wen Wang ◽  
Ming Lei ◽  
Gong-Rang Li ◽  
Zhi-Feng Duan ◽  
...  
Keyword(s):  
Rheological Properties ◽  
Drilling Fluids ◽  
Water Based

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.

scholarly journals Prediction of Formation Damage, Fluid Loss and Rheological Properties of Water Based Mud with Corn Cob

2020 ◽  
Vol 5 (10) ◽  
pp. 1269-1273
Author(s):  
Godwin Chukwuma Jacob Nmegbu ◽  
Bright Bariakpoa Kinate ◽  
Bari-Agara Bekee
Keyword(s):  
Rheological Properties ◽  
High Pressures ◽  
Chemical Properties ◽  
Analytical Models ◽  
Formation Damage ◽  
Fluid Loss ◽  
Drilling Mud ◽  
Corn Cob ◽  
Core Samples ◽  
Water Based

The extent of damage to formation caused by water based drilling mud containing corn cob treated with sodium hydroxide to partially replace polyanionic cellulose (PAC) as a fluid loss control additive has been studied. Core samples were obtained from a well in Niger Delta for this study with a permeameter used to force the drilling mud into core samples at high pressures. Physio-chemical properties (moisture content, cellulose and lignin) of the samples were measured and the result after treatment showed reduction. The corn cob was combined with the PAC in the ratio of 25-75%, 50-50% and 75-25% in the mud. Analyzed drilling mud rheological properties such as plastic viscosity, apparent viscosity, yield point and gel strength all decreased as percentage of corn cob increased in the combination and steadily decreased as temperature increased to 200oF. Measured fluid loss and pH of the mud showed an increase in fluid loss and pH in mud sample with 100% corn cob. The extent of formation damage was determined by the differences in the initial and final permeability of the core samples. Experimental data were used to develop analytical models that can serve as effective tool to predict fluid loss, rheological properties of the drilling mud at temperature up to 200oF and percentage formation damage at 100 psi.

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