Best Practices for the Logging While Drilling Fluid Sampling of Deviated Wells in Deepwater Applications

2014 ◽  
Author(s):  
Stephen John Martin ◽  
Pei-chea Tran ◽  
Steven Marshall
Keyword(s):  
Best Practices ◽  
Drilling Fluid ◽  
Logging While Drilling ◽  
Fluid Sampling ◽  
Deviated Wells

A novel lateral resistivity logging-while-drilling (LWD) method in oil-based drilling fluid

2017 ◽  
Author(s):  
Junyi Lu ◽  
Baoliang Wang ◽  
Haifeng Ji ◽  
Xin Li ◽  
Weining Ni ◽  
...  
Keyword(s):  
Drilling Fluid ◽  
Logging While Drilling ◽  
Resistivity Logging

Wavefield simulation and analysis with the finite-element method for acoustic logging while drilling in horizontal and deviated wells

Geophysics ◽  
2013 ◽  
Vol 78 (6) ◽  
pp. D525-D543 ◽  
Author(s):  
Hua Wang ◽  
Guo Tao ◽  
Kuo Zhang
Keyword(s):  
Finite Element Method ◽  
Finite Element ◽  
Complex Frequency ◽  
The Finite Element Method ◽  
Wavefield Simulation ◽  
Bottom Hole Assembly ◽  
Logging While Drilling ◽  
Assembly Performance ◽  
Element Method ◽  
Deviated Wells

We developed a frequency-domain finite-element method (FFEM) in conjunction with a complex-frequency-shifted perfectly matched layer (CFS-PML) boundary to effectively study the wavefield generated by acoustic multipole logging-while-drilling (LWD) tools in horizontal and highly deviated wells. With such an FFEM, the sources and receivers can be easily set symmetrically in the simulation to model the real tools exactly, while this is very difficult to deal with in the finite-difference method. In addition, the CFS-PML boundaries can be implemented more efficiently in this algorithm. We applied this method to study the effects of tool eccentricity on the measurements in slow formations that most likely need 3D solutions for LWD in horizontal and highly deviated wells. We found that because the tool cannot be centralized in these wells, some nonmonopole modes could appear in monopole measurements and the Stoneley mode could appear in dipole measurements; the flexural collar wave could become increasingly strong with an increase of tool eccentricity, and the Stoneley mode may be the later arriving event, especially in the case of a severely eccentric quadrupole tool. Based on these studies, we introduced a method to quantify the extent and the angle of the tool eccentricity with the phase difference in eccentric dipole measurements. These parameters are very useful for the analysis of the bottom-hole assembly performance in geosteering.

Cuttings Bed Removal in Deviated Wells

2018 ◽  
Author(s):  
Jan David Ytrehus ◽  
Bjørnar Lund ◽  
Ali Taghipour ◽  
Birgitte Ruud Kosberg ◽  
Luca Carazza ◽  
...  
Keyword(s):  
Test Section ◽  
Critical Angle ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Drill String ◽  
Flow Loop ◽  
Cleaning Efficiency ◽  
Hole Cleaning ◽  
Low Viscosity ◽  
Deviated Wells

A drilling fluid for drilling deviated wellbores must provide adequate hole cleaning efficiency for all well angles relevant to the operation. For angles near vertical, experience show that hole cleaning is straight forward. In wellbore angles larger than, say, 45 degrees hole cleaning is more difficult. Cuttings beds are formed and at some well angles these beds may avalanche during circulation stops etc. This paper presents results from laboratory tests with injected cuttings using a low viscosity oil based drilling fluid with micronized grained barite as weight material. The fluid is designed for highly deviated wells with low ECD requirements and the cuttings transport performance through relevant wellbore inclinations was investigated. The experiments have been performed under realistic conditions. The flow loop includes a 10 meters long test section with 2” OD freely rotating steel drill string inside a 4” ID wellbore made of steel, representing a cased wellbore. Sand particles were injected while circulating the drilling fluid through the test section. Experiments were performed in three wellbore inclinations: 48, 60 and 90 degrees from vertical. Results show that hole cleaning in absence of drill pipe rotation is significantly improved if the well angle is less than a critical angle. This critical angle appears to be less than 60 degrees from vertical. Further result show that this critical inclination angle is dependent to the drill string rotation rate and the annular flow velocity.

scholarly journals Impact of drilling fluid viscosity, velocity and hole inclination on cuttings transport in horizontal and highly deviated wells

2012 ◽  
Vol 2 (3) ◽  
pp. 149-156 ◽  
Author(s):  
Ali Piroozian ◽  
Issham Ismail ◽  
Zulkefli Yaacob ◽  
Parham Babakhani ◽  
Ahmad Shamsul Izwan Ismail
Keyword(s):  
Drilling Fluid ◽  
Fluid Viscosity ◽  
Cuttings Transport ◽  
Deviated Wells

scholarly journals Analysis and application of prediction model for formation fluid sampling time while drilling

2021 ◽  
Vol 267 ◽  
pp. 01018
Author(s):  
Zhongshuai Chen ◽  
Hongjian Ni ◽  
Chuanlong Jiang ◽  
Yang Zhang ◽  
Hui Zhang
Keyword(s):  
Drilling Fluid ◽  
Prediction Method ◽  
Operation Time ◽  
Field Application ◽  
Sampling Time ◽  
Contamination Rate ◽  
Drilling Mud ◽  
Short Operation Time ◽  
Drilling Conditions ◽  
Fluid Sampling

Formation sampling while drilling (FSWD) is one of the most advanced formation sampling techniques in the world. It is characterized by short operation time, shallow mud invasion, and the obtained formation data is closer to the real situation of the reservoir. During the sampling process, the first fluid that the suction probe on the borehole wall inhales is basically drilling mud filtrate. With the increase of suction time, it gradually mixes into the formation fluid, and finally the formation fluid is infinitely close to 100%. At this time, it is very important to judge the starting time of sampling. If the sampling time is too early, the percentage of samples contaminated by drilling filtrate will be higher, which can not meet the requirement of fidelity. If the sampling time is too late, the drilling fluid will stop circulating for too long, which will cause sticking. In this paper, the prediction method of sampling time is to simulate the permeability of drilling fluid to formation under certain formation parameters and drilling conditions. Based on the simulated permeability results, the suction model of sampling tool is established to simulate the pumping situation, and the variation of the content of drilling filtrate in the pumped fluid with the suction time is obtained, that is, the relationship between the contamination rate of formation fluid and the suction time, This method is of great significance to the field application of fluid sampling tools while drilling.

Development of Drilling Fluid Advisory System Utilizing Bayesian Network

2021 ◽  
Author(s):  
Abdullah Saleh Al-Yami ◽  
Vikrant B Wagle ◽  
Mohammed Murif Al-Rubaii ◽  
Ziaudeen Abubacker
Keyword(s):  
Best Practices ◽  
Drilling Fluid ◽  
Bayesian Probability ◽  
Drilling Fluids ◽  
Bayesian Decision ◽  
Data Set ◽  
Advisory System ◽  
Field Samples ◽  
Bayesian Decision Network ◽  
The Right

Abstract Using the right drilling fluid with optimal rheology and filtration properties is one of the most important factors in successful drilling and completion operations. Designing the right drilling fluid depends on a variety of factors viz. formation lithology, wellbore geometry, temperature, pressure, and drilling objectives. To the best of the author's knowledge there is no standard drilling fluid advisory system to aid drilling engineers and scientists to formulate effective drilling fluids systems for the entire well sections. The paper describes a drilling fluid advisory system based on Artificial Bayesian Intelligence. The advisory system includes a Bayesian decision network (BDN) model that receives inputs and outputs recommendations based on Bayesian probability determinations. This advisory system has been designed to aid drilling engineers when designing drilling fluids for their operations. This paper describes a module that was created in this advisory system. This module was created based on several inputs viz. well geometry (vertical and horizontal), temperature, pressure, productivity. To create the drilling fluids module within the advisory system, a number of drilling fluid specialists/experts were interviewed to gather the information required to determine the best practices as a function of the above inputs. These best practices were then used to build decision trees that would allow the user to take an elementary data set and end up with a decision that honors the best practices. The designing process of this advisory system also included a number of standard lab tests that start from quality assurance, initial designing and finally using field samples to confirm the success of the application. The study also discusses several field cases that validate the drilling fluids advisory system. The novel drilling fluid advisory system based on Artificial Bayesian Intelligence has been designed to aid drilling engineers and scientists to formulate effective drilling fluids systems for the entire well sections.

scholarly journals Evaluating the effect of drill string rotation and change in drilling fluid viscosity on hole cleaning

2021 ◽  
Author(s):  
Samuel Bright Olawale ◽  
Promise O. Longe ◽  
Samuel Felix Ofesi
Keyword(s):  
Drilling Fluid ◽  
High Viscosity ◽  
Drill String ◽  
Rheological Parameters ◽  
Fluid Viscosity ◽  
Hole Cleaning ◽  
Low Viscosity ◽  
Cutting Bed ◽  
Viscosity Fluid ◽  
Deviated Wells

AbstractThe most primitive hole challenge is cleaning the hole, which is more severe in deviated wells. This problem was tackled in this research via experimental analysis and graphical evaluations. To hit this aim, rheological parameters were experimentally obtained, and Noah’s model was used to determine cutting bed erosion time at varying heights. A graphical evaluation was done using a case study of deviated wells X and Y from a Niger Delta field. The result shows that low-viscosity fluid, KCL polymer fluid and high-viscosity fluid take 124, 283 and 342 min, respectively, to erode equal height as graphical evaluation shows that hole cleaning will grow complex on deviation. Thus, the deduction from this work in reducing non-productive time (NPT) related to hole cleaning in drilling operation is first, prior to making a trip, pumping low-viscosity fluid at a high flow rate. Secondly, during drilling, increasing drill string rotation in deviated wells can effectively stir the cuttings into the annulus above the low session of the hole.

Innovative Drilling Fluid Technology Conquered Tough Geomechanics Offshore Mexico

2021 ◽  
Author(s):  
Ricardo Reyna ◽  
Viridiana Parra ◽  
Daniel Volbre ◽  
Raul Ballinas ◽  
Reinaldo Maldonado ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Best Practices ◽  
Drilling Fluid ◽  
Cost Savings ◽  
Lessons Learned ◽  
New Production ◽  
Wellbore Instability ◽  
High Pressure High Temperature ◽  
Intermediate Section

Abstract The reservoir field highlighted in this paper is located Offshore Mexico in the southeast part of Campeche Bay and hidden below a troublesome, unstable formation that must be transacted before reaching the new production zone. During the exploration phase, this section experienced severe lost circulation and unstable conditions before reaching the final depth. Based on lessons learned, the team worked to develop a best- practices approach using geomechanics analysis and a novel fluid technology which enabled the operator to safely drill through this problematic intermediate section under high-pressure, high-temperature (HPHT) conditions. The methodology started with identifying the geomechanics challenges, implementing operational best practices, and finally, use of an innovative, low-invasion fluid technology, which creates a thin and impermeable shield at the wellbore wall, effectively sealing the fractures and preventing fracture propagation in the highly unstable formation of interspersed carbonates, shales, and sandstones. The strong mechanical properties of the thin, but firm, barrier created at the wellbore wall minimized the destabilizing effect of fluid invasion. Synergy from the geomechanical team, best practices for the operation, and innovative drilling fluid technology solved the wellbore instability drilling challenge encountered in the exploration well. In offset wells, losses of more than 2,200 m3 of drilling fluid, stuck pipe, and major NPT were observed. By incorporating the shielding technology, wellbore instability was improved in the intermediate section. In addition, the fluid technology was easily pumped through the bottomhole assembly (BHA) to seal formation fractures between 2,000 and 3,000 μm in size. This well, utilizing the barrier technology to mitigate the wellbore instability and drill within a narrow fracture gradient operating window, was the first in the area to have zero loss of drilling fluid as compared to the typical 5 to 10-m3/hr circulation losses experienced during exploration drilling in the intermediate section characterized by interbedded layers of carbonates, shales, and sandstone under high-pressure, high-temperature (HPHT) conditions. The coordination between the teams using best practices was critical to meeting the challenge of the intermediate geomechanically weak formation. This case history in offshore Mexico will demonstrate both the importance of teamwork and the utilization of a proven technology that improves wellbore instability, minimizes NPT, mitigates pipe tripping issues and avoids huge volumes of drilling fluid lost into the geomechanically weak formation. This barrier technology can be applied globally to troublesome formations - such as interbedded carbonates, shales, and sandstones - to improve operations and provide cost savings for the operator.

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