scholarly journals Efficient Removal of Magnetic Contamination from Drilling Fluids - The Effect on Directional Drilling

2020 ◽  
pp. 1-14
Author(s):  
Arild Saasen ◽  
Benny Poedjono ◽  
Geir Olav Ånesbug ◽  
Nicholas Zachman
Keyword(s):  
Magnetic Particles ◽  
Barents Sea ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Directional Drilling ◽  
The North ◽  
Uncertainty Calculation ◽  
The North Sea ◽  
Drilling Rigs ◽  
Sea Area

Abstract Magnetic debris in a drilling fluid have a significant influence on the ability of the drilling fluid to maintain its function. Down hole logging can suffer from poor signal to noise ratios. Directional drilling in areas close to the magnetic North Pole, such as in the Barents Sea, Northern Canada or Russia can suffer because of magnetic contamination in the drilling fluid. Magnetic particles in the drilling fluid introduce additional errors to the magnetic surveying compared to those normally included in the ellipsoid of uncertainty calculation. On many offshore drilling rigs, there are mounted ditch magnets to remove metallic swarf from the drilling fluid. These magnets normally only remove the coarser swarf. In this project, we use a combination of strong magnets and flow directors to significantly improve the performance of the ditch magnets. This combination, together with proper routines for cleaning the ditch magnets, significantly helps to clean the drilling fluid. Through the combined use of flow directors and ditch magnets, it was possible to extract more than five times as much magnetic contamination from the drilling fluid as normal compared with other proper ditch magnet systems. This is verified by comparing the ditch magnet efficiencies from two drilling rigs drilling ERD wells in the North Sea area. In the paper, it is discussed how the accuracy of directional drilling and well position effected by various interferences can be improved by the use of a drilling fluid with minimal effect to the MWD measurement.

Removal of Magnetic Contamination in Drilling Fluids: Effect on Directional Drilling

2020 ◽  
Author(s):  
Arild Saasen ◽  
Benny Poedjono ◽  
Geir Olav Ånesbug ◽  
Nicholas Zachman
Keyword(s):  
Magnetic Particles ◽  
Barents Sea ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Directional Drilling ◽  
The North ◽  
Uncertainty Calculation ◽  
The North Sea ◽  
Drilling Rigs ◽  
Sea Area

Abstract Magnetic debris in a drilling fluid have a significant influence on the ability of the drilling fluid to maintain its function. Down hole logging can suffer from poor signal to noise ratios. Directional drilling in areas close to the magnetic North Pole, such as in the Barents Sea, Northern Canada or Russia can suffer because of magnetic contamination in the drilling fluid. Magnetic particles in the drilling fluid introduce additional errors to the magnetic surveying compared to those normally included in the ellipsoid of uncertainty calculation. On many offshore drilling rigs, there is mounted ditch magnets to remove metallic swarf from the drilling fluid. These magnets normally only remove the coarser swarf. In this project, we use a combination of strong magnets and flow directors to significantly improve the performance of the ditch magnets. This combination, together with proper routines for cleaning the ditch magnets, significantly helps to clean the drilling fluid. Through the combined use of flow directors and ditch magnets, it was possible to extract more than five times as much magnetic contamination from the drilling fluid as normal compared with other proper ditch magnet systems. This is verified by comparing the ditch magnet efficiencies from two drilling rigs drilling ERD wells in the North Sea area. In the paper, it is discussed how the accuracy of directional drilling and well position effected by various interferences can be improved by the use of a drilling fluid with minimal effect to the MWD measurement.

High Geostress Advantageous for Arctic Field Developments

2018 ◽  
Author(s):  
Bernt S. Aadnøy ◽  
Mesfin A. Belayneh
Keyword(s):  
Stress State ◽  
North Sea ◽  
Barents Sea ◽  
Wellbore Stability ◽  
The Arctic ◽  
Positive Effects ◽  
The North ◽  
The Barents Sea ◽  
The North Sea ◽  
Sea Area

The Arctic areas of Norway has brought many new challenges. In addition to harsh weather, drilling conditions are different. The Barents Sea is different geologically compared to the North Sea area. A considerable amount of erosion bring older rocks higher up. It is observed that leak-off tests measured in Barents Sea wells shows abnormally high values. This is interpreted as a high stress state. The paper analyze the stresses around a number of wells and conclude that it is very likely that a reverse fault stress state exists in these areas of the Barents Sea. This can bring positive effects because such a stress state may constrain induced fractures to propagate in a horizontal plane rather than towards surface, reducing the risk for reservoir leaks to surface. Also, a high compressive state may lead to more sealed faults, indicating a higher possibility for oil in place. The paper will present the stress model and compare Barent Sea area to the North Sea. It will also show implications for wellbore stability, leaks from reservoirs and effects on sealing of major faults. Of particular interest is that leak potential from the reservoir is reduced in the Barent Sea as compared to other Norwegian oil fields. This may encourage more development in the Arctic areas.

Automated Drilling-Fluids-Measurement Technique Improves Fluid Control, Quality

2021 ◽  
Vol 73 (11) ◽  
pp. 53-54
Author(s):  
Chris Carpenter
Keyword(s):  
Ambient Temperature ◽  
North Sea ◽  
Drilling Fluid ◽  
Pressure Sensors ◽  
Drilling Fluids ◽  
Sampling Point ◽  
Electrical Stability ◽  
The North ◽  
Fluid Properties ◽  
The North Sea

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 204041, “Automatic Drilling-Fluids Monitoring,” by Knut Taugbøl, SPE, Equinor, and Bengt Sola and Matthew Forshaw, SPE, Baker Hughes, et al., prepared for the 2021 SPE/IADC International Drilling Conference and Exhibition, originally scheduled to be held in Stavanger, 9–11 March. The paper has not been peer reviewed. The complete paper presents new units for automatic drilling-fluids measurements with emphasis on offshore drilling applications. The surveillance of fluid properties and the use of data in an onshore operations center is discussed. The authors present experiences from use of these data in enabling real-time hydraulic measurements and models for automatic drilling control and explain how these advances can improve safety in drilling operations and drilling efficiency. Introduction An operator has worked with different suppliers for several years to find and develop technology for automatic measurements of drilling-fluid properties. In the described study, methods for measuring parameters such as viscosity, fluid loss control, pH, electrical stability, particle-size distribution, and cuttings morphology and mineralogy were all fitted into a flow loop in an onshore test center. These tests, however, were all performed with prototype equipment. Since then, work has continued to optimize equipment for offshore installations, made for operating in harsh environments and requiring limited maintenance to provide continuous and reliable data quality. The fluid-measuring technique presented in this paper is based on rheology measurement through a pipe rheometer and density measurements through a Coriolis meter. This rheometer measures at ambient temperature. Dual DP is the terminology that refers to pressure measurements between two differential pressure sensors. The dual-DP pipe rheometer is set up with high-accuracy pressure transducers to measure pressure loss inside the straight section of the pipe rheometer. By varying the flow rate through pipes of different dimensions, a rheology profile at varying shear rates can be calculated. Field Implementation Installation of a unit begins with a rig survey conducted in concert with the drilling contractor to find the best location and sampling point. Fluid normally is taken from the charge manifold for the mud pumps, ensuring measurement of the fluid going into the well. The first installation in the North Sea of an automatic fluid-monitoring (AFM) unit was in 2017. This unit is still operational, sending data to an onshore support center. Fig. 1 shows such a unit installed offshore. The AFM unit has only one movable part, the monopump supplying drilling fluid through the unit. Once the dual-DP rheometer was factory-acceptance-tested in the yard, it was sent offshore to be commissioned and verified on a fixed installation in the North Sea. The related data presented in the complete paper were acquired in the field while drilling the 355-m, 8½-in. section with 1.35-SG low-equivalent-circulating-density oil-based drilling fluid, with drilling conducted at approximately 4000 m measured depth. The mud engineer onboard was requested to perform rheology checks on a viscometer at equal ambient temperature to the AFM so that the results could be compared; the AFM also measures rheology at ambient temperature.

Subsidence and sea-level rise in the Thames Estuary

1972 ◽  
Vol 272 (1221) ◽  
pp. 121-130 ◽  
Keyword(s):  
Sea Level Rise ◽  
Sea Level ◽  
Average Rate ◽  
Thames Estuary ◽  
The North ◽  
Storm Waves ◽  
Late Cretaceous Period ◽  
The North Sea ◽  
Sea Area ◽  
Cretaceous Period

The development of the area, of the Thames Estuary is briefly traced since the late Cretaceous period, with its present outline being due to a combination of factors. The overall subsidence of the North Sea area, the ‘Alpine5 fold movements, and the transgression of the sea since the retreat of the Weichselian icesheets have all contributed. The positions of the shore-line during the critical phase, 9600 b.p. to 8000 b.p., of this last transgression of the sea are shown. Subsequent to this main transgressive phase, erosion of the shoreline has been rapid due to storm-waves and tidal current action. An estimation of the average rate of subsidence and/or sea-level rise is given based on the concept of sedimentary equilibrium in which a figure of 12.7 cm (5 in) per century is arrived at.

scholarly journals Complexes for continuous monitoring of drilling fluid parameters during drilling

2021 ◽  
Vol 6 (3) ◽  
pp. 144-151
Author(s):  
Sergey V. Lakhtionov ◽  
Ivan S. Chumakov ◽  
Sergey G. Filinkov ◽  
Dmitry M. Chukin ◽  
Evgeny N. Ishmetyev
Keyword(s):  
Continuous Monitoring ◽  
Drilling Fluid ◽  
Point Of View ◽  
Complete Analysis ◽  
Drilling Fluids ◽  
Automatic Mode ◽  
Design Values ◽  
Drilling Rigs ◽  
Almost All ◽  
Fluid Parameters

Background. The article provides an overview of existing complexes (units) for continuous monitoring of drilling fluid parameters in automatic mode. Aim. To justify the need to develop a complex (module) that will allow combining existing technologies and making a step forward in the field of process automation in terms of monitoring the parameters of drilling fluids. Materials and methods. In the current realities of well construction, the control of drilling fluid parameters on almost all drilling rigs operating on the territory of Russia (possibly with the exception of a few off shore projects) is carried out by the work of a solution engineer, usually a representative of a service company. The analysis of the parameters, depending on the number of personnel, the speed of penetration, the complexity or importance of the well, can be carried out from 2 to 6 times a day [1, 2]. This means a complete analysis, rather than monitoring the density and conditional viscosity, which can be measured by a representative of the drilling crew, for rapid response, and with greater frequency. Due to such a low measurement discreteness, there is a high probability of a significant deviation of the drilling fluid parameters from the design values. As a result, the probability of various complications, both geological and technological, increase significantly. Results. During the analysis of information from open sources, the most promising complexes (modules) from the point of view of application in the current conditions were identified, their positive and negative sides were evaluated. As a result of the conducted review of open sources, the most promising complexes (modules) in terms of application in the current conditions are identified, the positive and negative sides of the systems under consideration are displayed, and the need to develop a complex (module) that will combine all the best that is available today and make a qualitative step forward in the field of “peopleless” technologies used during drilling wells in terms of monitoring the parameters of drilling fluids is justified. Conclusions. The necessity of developing a complex (module) for automating processes in terms of monitoring the parameters of drilling fluids is justified.

A Case History of Casing Directional Drilling in the Norwegian Sector of the North Sea

2008 ◽  
Author(s):  
Kevin Arthur Bourassa ◽  
Tove Husby ◽  
Rick Deuane Watts ◽  
Dale Oveson ◽  
Tommy M. Warren ◽  
...  
Keyword(s):  
North Sea ◽  
Case History ◽  
Directional Drilling ◽  
The North ◽  
History Of ◽  
The North Sea
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