Successful Field Application of an Electro-Negative 'Coating' to Reduce Bit Balling Tendencies in Water Based Mud

1996 ◽  
Author(s):  
Lee Smith ◽  
F.K. Mody ◽  
Arthur Hale ◽  
Nils Romslo
Keyword(s):  
Field Application ◽  
Water Based

Controlling Costs and NPT: An Economical Approach to Wellbore Strengthening Offshore Vietnam

2021 ◽  
Author(s):  
Kishen Nanda Kumar ◽  
Luigi Moroni ◽  
Abhijart Kongto ◽  
Bao Tran Thanh ◽  
Nghia Nguyen Hoang ◽  
...  
Keyword(s):  
Field Application ◽  
Wellbore Stability ◽  
Particle Size Range ◽  
Product Consumption ◽  
Application Procedure ◽  
Water Based ◽  
Wellbore Strengthening ◽  
Fracture Apertures ◽  
Fluid Design ◽  
Stability Issues

Abstract There are many challenges while drilling highly inclined and depleted formations offshore Vietnam that result in various wellbore stability issues such as severe losses, stuck pipe, cavings, tight-hole and pack-offs. These issues may be independent of mud type and can occur when drilling with both oil/synthetic-based and water-based muds. These depleted sections typically consist of sandstones interbedded with claystone & siltstones. Traditionally, the wellbore strengthening fluids solution applied to drill through these sections with synthetic and water-based mud in Vietnam faced limited success. Wellbore strengthening (WBS) is a proven and effective solution especially for narrow-drilling margin and depleted formations. The basic concept of WBS relies on the creation and simultaneous plugging of small fractures with appropriate WBS material. The resulting elevated stress around the wellbore strengthens the borehole by creating an increased hoop stress that leads to an increase in near wellbore stresses. Proprietary modelling software can be used to calculate the pressure induced fracture apertures for wellbore strengthening applications and determine the optimum particle size range to bridge these fractures, allowing fluids to be designed to minimise wellbore instability. This design process was used to optimize material additives to effectively bridge fractures, for wellbore strengthening, and pore throat openings in porous/permeable formations for the prevention of seepage losses and differential sticking. A review of the application procedure identified the optimum method to apply the wellbore strengthening material which would minimise product consumption and reduce well costs. After extensive modelling simulations and testing, this fluid design was applied to drill two challenging wells in Vietnam. This paper presents the process of modelling, based on formation geo-mechanics information, customization and laboratory testing of the fluids design coupled with a successful and economical method of application in the field. Application of this process enabled the operator to drill through the depleted challenging sections with a maximum overbalance pressure of 3,200 psi, conduct logging and coring runs and complete the well at a lower cost and with zero fluids related non-productive time compared to previous wells.

Laboratory Development and Field Application of a Novel Water-Based Drill-In Fluid for Geopressured Horizontal Wells

1996 ◽  
Author(s):  
J.W. Dobson ◽  
J.C. Harrison ◽  
A.H. Hale ◽  
H.C. Lau ◽  
L.A. Bernardi ◽  
...  
Keyword(s):  
Horizontal Wells ◽  
Field Application ◽  
Water Based ◽  
Laboratory Development

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.

Application Study of Phase Inversion for Drilling Fluid in Well Lianhua 000-X2#

2012 ◽  
Vol 524-527 ◽  
pp. 1153-1156
Author(s):  
Li Yang ◽  
Yun Peng An ◽  
Nan Tian ◽  
Jun Ma ◽  
Jian Hua Yao
Keyword(s):  
Phase Inversion ◽  
Solid Phase ◽  
Drilling Fluid ◽  
Stability Loss ◽  
Field Application ◽  
Application Study ◽  
Well Control ◽  
Root Cause ◽  
Colloidal Properties ◽  
Water Based

In order to reduce the flow resistance of a water-based drilling fluid, emulsifiers tend to be added into the drilling fluid mixed with oil at the same time. However, inappropriate proportion or oil-based pipe free agent with low HLB value could easily trigger the phase inversion of the drilling fluid, causing its stability loss or even water–solid separation. Therefore, starting from the root cause of the phase inversion, the surfactivity of solid-phase materials in the drilling fluid was changed from hydrophobicity to hydrophilicity by adding surfactants with high HLB value. Then its colloidal properties were reestablished by combining alkali diluting agent, and the drilling fluid with phase inversion of well Lianhua 000-X2# was treated indoors. The results of the field application in the well show that high-HLB surfactant can solve the phase inversion of a water-based drilling fluid properly, and that barite sedimentation and well control problem, caused by the phase inversion of the water-based drilling fluid with high-density, can be avoided.

Laboratory Development and Field Application of a Novel Water-Based Drill-In Fluid for Geopressured Horizontal Wells

2000 ◽  
Vol 15 (02) ◽  
pp. 105-111 ◽  
Author(s):  
J.W. Dobson ◽  
J.C. Harrison ◽  
A.H. Hale ◽  
H.C. Lau ◽  
L.A. Bernardi ◽  
...  
Keyword(s):  
Horizontal Wells ◽  
Field Application ◽  
Water Based ◽  
Laboratory Development

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.

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.

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