The Experimental Measurement of Casing Wear Due to Tripping—Part 1: Drill Pipe Wear

1975 ◽  
Vol 97 (2) ◽  
pp. 445-455
Author(s):  
J. E. Fontenot ◽  
J. W. McEver
Keyword(s):  
Experimental Investigation ◽  
Experimental Measurement ◽  
Field Data ◽  
Drill Pipe ◽  
Major Conclusion ◽  
Full Size ◽  
Contact Loads ◽  
Casing Wear ◽  
Water Base ◽  
Wear Tests

An experimental investigation was undertaken to explore the effects of various factors on casing wear due to tripping drill pipe. Wear tests were run using full-size samples of casing and drill pipe at various contact loads in water, a gel mud containing sand, and in a 14-lb/gal water base mud containing various quantities of simulated drill solids. The wear results were compared with field data. The major conclusion is that tripping drill pipe is generally not a major cause of casing wear.

The Experimental Measurement of Casing Wear Due to Tripping—Part 2: Wire-Line Wear

1975 ◽  
Vol 97 (2) ◽  
pp. 456-463
Author(s):  
J. E. Fontenot ◽  
J. W. McEver
Keyword(s):  
Experimental Investigation ◽  
Experimental Measurement ◽  
Major Conclusion ◽  
Full Size ◽  
Line Wear ◽  
Contact Loads ◽  
Casing Wear ◽  
Water Base ◽  
Wear Tests

An experimental investigation was undertaken to explore the effects of various factors on casing wear due to running wire line. Wear tests were run using full-size samples of casing and wire line. Tests were run at various contact loads in water, a gel mud containing sand, and in a 14-lb/gal water base mud containing various quantities of simulated drill solids. The major conclusion reached is that the presence of abrasive solids in the mud greatly accelerates wire-line wear.

An Experimental Evaluation of Drill Pipe Protectors

1977 ◽  
Vol 99 (1) ◽  
pp. 199-207
Author(s):  
W. B. Bradley
Keyword(s):  
Quality Control ◽  
Experimental Evaluation ◽  
Drill Pipe ◽  
Test Results ◽  
Contact Loads ◽  
Casing Wear ◽  
Low Rate

Previous tests [1] have shown drill pipe protectors are of value in reducing casing wear, particularly at high contact loads. However, the brand of protectors tested could not withstand high contact loads without slipping on the drill pipe and tearing apart. As a result, further tests were conducted to find a protector which can withstand high contact loads without slipping or failing and still minimize casing wear. Results from the present tests show that drill pipe protectors can be made to operate at high contact loads without failure, grip the drill pipe without slipping, and maintain a low rate of casing wear. In addition, the test results indicate that drill pipe protector quality control needs to be improved.

Minimizing Casing Wear in Dog Legs

1977 ◽  
Vol 99 (1) ◽  
pp. 215-223 ◽  
Author(s):  
W. B. Bradley
Keyword(s):  
Drill Pipe ◽  
Field Measurements ◽  
Experimental Information ◽  
Wear Performance ◽  
Wear Rates ◽  
Casing Wear

Procedures are presented for estimating the amount of casing wear produced in wells by the rotation of tool joints, drill pipe, and drill pipe protectors against casing. The procedures are based upon experimental information and limited field measurements developed over a period of several years [1–5]. The procedures have been used with moderate success in predicting the casing wear rates seen in the field for a limited number of cases. The paper again emphasizes that with the proper use of drill pipe protectors casing wear can be minimized. In addition, the paper presents suggested procedures for selecting drill pipe protectors to assure consistent casing wear performance.

A Practical Study of the Influence of Drill Solids on the Corrosion of Downhole Tubulars When Using Brine Based Drilling Fluids

2021 ◽  
Author(s):  
Garett Heath ◽  
Temi Okesanya ◽  
Simon Levey
Keyword(s):  
Oxygen Content ◽  
Field Data ◽  
Drill Pipe ◽  
American Petroleum Institute ◽  
Filter Press ◽  
Drilling Fluids ◽  
Chemical Additives ◽  
Active System ◽  
Corrosion Rates ◽  
Fluid Properties

Abstract The proliferation of highly concentrated brine drilling fluids systems due to their enhanced performance benefits has instigated a plethora of technical studies on the mechanisms and control of their induced corrosion on downhole drilling tools and tubulars. The majority of these studies often overlook the effect of drill solids on corrosion rates. Therefore, a pragmatic and experimental study was conducted to investigate the effects of various factors on the corrosion rates of downhole tubulars with a streamlined focus on the obscure role of the understudied drill solids; which have not been fully elucidated. Drill pipe corrosion coupons and drilling fluids/solids obtained from 5 similar wells (located in Grande Prairie, Alberta, Canada) were utilized for experimental analysis. Wells 1 to 4 were on the same pad (surface drilling location) drilling the same formation with the same fluid properties, while the 5th well was on a different pad but drilled the same formation with the same fluid properties to exclude disparity. Industry-standard measurement was carried out on the live used corrosion coupon rings, drilling fluids and solids obtained from these wells to determine selected properties. The total solids content analysis was carried out using an OFITE API (American Petroleum Institute) filter press. Weight loss tests on drill pipe corrosion coupons were used to determine field corrosion rates which were bolstered with the Parr Hastelloy autoclave test in the Laboratory. The oxygen content was monitored using Hach 2100Q dissolved oxygen meter. Field data, images and experimental results showed that a rapid and minuscule increase of drill solids (as little as 1% v/v) in the active system can impact corrosion rates greater than chemical additives and even oxygen content. It was discovered that low concentration of solids can produce significant damage and a high corrosion potential in non-viscosified fluids thereby making live monitoring of drilling fluids’ properties a priority to mitigate corrosion. This study fills an important technical gap in corrosion study that is indispensable for the optimization of corrosion control in drilling operations. By carrying out a controlled and investigative study backed up with drilling field data and images, the effects of the less understood drill solids have been partially demystified.

Experimental Investigation of Mechanical Friction and Hydraulics for Liner Drilling and Liner Running

2016 ◽  
Author(s):  
Jan David Ytrehus ◽  
Ali Taghipour ◽  
Bjørnar Lund ◽  
Knud Richard Gyland ◽  
Arild Saasen
Keyword(s):  
Experimental Investigation ◽  
Friction Coefficient ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Drilling Fluids ◽  
Flow Loop ◽  
Cuttings Transport ◽  
Transport Efficiency ◽  
Sand Particles ◽  
Norwegian Continental Shelf

The mechanical friction of liner operations is investigated and compared to what is expected for a conventional drill pipe. In addition the cuttings transport efficiency for realistic conditions is studied. The work is also relevant for running completion strings. This article is based on results from laboratory scale flow loop for drilling applications. Sand particles were injected while circulating the drilling fluid through the test section in some of the tests. The procedures used to conduct the experiments are explained and experimental results and observations are discussed. The drilling fluids and additives in these experiments are similar to those used in in fields on the Norwegian Continental Shelf (NCS). Friction coefficient is calculated from the measured torque for different flow velocities and rotational velocities and the force perpendicular to the surface caused by the buoyed weight of the string.

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