bluuebunny/crossref_metadata_2025_split huggingface dataset:
Operator's Recommendation for a Uniform Dull Grading System for Fixed Cutter Hole Enlargement Tools
Authors: Ulvedal L. , Enterline J. D. , Scott D. , Radford S. , Clinkscales J. , Shale L. , Croxton M. 
Published: March 2011

Abstract
An IADC standard system was defined and implemented in 1987 with revisions in 1992 to standardize and permit the accurate dull grading of fixed cutter bits. Now as hole enlargement is one of the fastest growing sectors of today's drilling industry, there is a greater need for an accurate and uniform dull grading system for fixed cutter hole enlargement tools. Through collaboration between an operator and a bit manufacturer, this new dull grading protocol is being proposed to better characterize hole enlargement tool dull conditions. The method will be described in this paper and will encompass concentric, eccentric, and expandable tools. It will define common elements of hole enlargement tool cutting structures and the dull grades relating to this BHA component as they differ from drill bits. Adoption of this new dull grading system for fixed cutter hole enlargement tools will facilitate an industry-wide standard to more accurately communicate dull conditions. This will enable operators, drilling contractors, and bit manufacturers to improve the tool's design, selection, and operating parameters for future applications.
Underreamer Dynamics
Authors: Meyer-Heye B. , Reckmann H. , Ostermeyer G.-P. 
Published: March 2011

Abstract
In a hole-opening application, cutting forces are applied to the drillstring simultaneously at the bit and the underreamer. Cutting forces at the reamer are known widely in the industry to cause additional vibrations of the drillstring that could harm the bottomhole assembly (BHA). This causes unnecessary downtime at the rigsite and increases costs. Expandable underreamers have very limited design envelopes for the optimization of their cutter layout. Most have only three blades and high-profile angles. Common polycrystalline diamond compact (PDC) bits have five or more blades and generate most of the cutting forces at their inner cutters. Reamers, due to their resulting forces, have significantly different characteristics compared to bits. By using appropriate bit-dynamics simulation software it is possible to explain the reasons for these different bit and reamer characteristics. An in-depth study of the cutting forces enables a better understanding of the mechanics of vibration excitation, especially for underreamers.
Dynamic cutting force models for bits and reamers have been developed based on the results of cutting force analyses. These models contain weight, torque, and residual side force. They were implemented into a highly sophisticated drillstring model using finite-element analysis. Dynamics simulations in time domain of complete drillstrings resulting from the cutting forces at the bit and reamer are shown. Interactions of the pilot bit and reamer coupled by the BHA are also investigated using this model.
A field test was conducted using a hydraulically expandable underreamer. During this test, simultaneous dynamics measurements where taken at the bit and reamer in vertical and directional well sections. The measurements validate the simulation results.
Increased Rate of Penetration Through Automation
Authors: Dunlop J. , Isangulov R. , Aldred W. D. , Sanchez H. Arismendi , Flores J. L. , Herdoiza J. Alarcon , Belaskie J. , Luppens J. C. 
Published: March 2011

Abstract
Drilling lags behind other industries in the implementation of automation. One reason for this is the variability of drilling operations and uncertainty in knowing what is being drilled at any given time. A closed-loop system that continually monitors drilling parameters and drilling performance in real time and constantly adjusts weight on bit (WOB) and rotary speed (RPM) maximizes instantaneous rate of penetration (ROP). The system has been tested in more than 15 drilling operations around the world in both advise and control modes. Field tests show an improvement in ROP typically greater than 10% versus nonautomated operations. Maximum benefit is realized when automation is implemented by means of a closed-loop system, whereby the set points for WOB and RPM are directly fed to the controls of the drilling rig. The algorithm, the closed-loop system, and the performance improvement delivered by this system are currently subject to certain operational constraints, but these will be addressed by future enhancements.
Remotely Operated Top-Drive Casing-Running System Combined with New Cement Head Enables Major Oil Company to Improve Zonal Isolation and Cement Bonding with Enhanced Safety and Efficiency in Caspian Sea
Authors: Cummins Tracy , Abrahamsen Egill , Killoh Ian 
Published: March 2011

Abstract
Using conventional methods for landing and cementing casing strings in a surface wellhead for a major operator in the Caspian Sea resulted in zonal communication, mud and cement losses, and poor cement bonding.
Historically, rig up and rig down of conventional casing-running and cementing equipment required extensive manual handling and man-riding operations to be carried out on the critical path, with times of one hour being common. During this time circulation was not possible, leaving thixotropic well fluids static and turning them to a gelled state before cementing operations had begun. This gelling lead to channeling of fluids, mud/cement losses and poor cement placement.
To address these problems, a remotely operated top-drive casing-running tool in combination with a new, remotely operated cement head were deployed. Configured with upper and lower casing-handling joints, the new cement head enabled the top-drive casing-running system to quickly pick up the cement head and make it up into the landing string as a casing joint without manual handling. The cement head was preloaded with remotely launched top and bottom cement plugs and preinstalled plug valve with a cement hose, eliminating the need for man-riding operations.
Circulation through the top drive began immediately after makeup, keeping the casing and well fluids in motion to eliminate gelling. Cement was then pumped through the side port of the cement head, and the casing string was reciprocated throughout the entire operation with increased flow area past the casing hanger, allowing higher displacement flow rates, reducing formation pressures and improving cement placement. The casing string was held in tension during cement displacement.
This combination of new technologies has been successfully implemented to run several 9.625-in. and 13.375-in. casing strings in the previously problematic pseudo-ERD and conventional wells, resulting in: Decreased transition time (static pipe) between casing-running and cementing operationsReduced manual handling of equipment and elimination of man-riding operationsExcellent zonal isolation based on cement bond logsMinimized (in some cases eliminated) mud/cement losses during entire cement jobExcellent cement sealsSuccessful pressure tests
Rebuilding a Tool Joint: Best Practices to Avoid Failure
Authors: Pettit Grant , Gokhale Samit 
Published: March 2011

Abstract
Weld repair of tool joints ("rebuilding") has been practiced due to the manufacturing schedule and cost of new drill pipe. In rebuilding, a soft metal is welded to the tool joint surface to increase the outside diameter (OD) to meet Premium Class dimensional requirements. While expedient, welding on the outer surface of tool joints should be approached with caution, since the welding process re-heat treats the steel in an undesirable fashion, increasing the likelihood of an unexpected failure.
This paper presents the results from two failure analyses in different geographic regions. In one instance, an operator in the Middle East experienced a twistoff failure at the base of the 18° box taper. In the second case, an operator in Colorado had a washout at the same location. This second downhole failure prompted a Magnetic Particle Inspection (MPI) of the remainder of the string, which resulted in the rejection of several additional joints due to cracks in the same area, the base of the 18° box taper.
Analysis revealed that all of the problem tool joints had been rebuilt. In each case, soft metal was welded on the box OD surfaces, machined to a smooth finish, and placed back into service. The altered material properties of the tool joints made them susceptible to brittle cracking and fatigue failure.
This paper provides the lessons learned from these failure analyses, including field data and the metallurgical results. For those instances when tool joint rebuilding is performed, proper weld quality control procedures are outlined to reduce the risk of failures.
First Application of Heat-Activated, Rigid Rapid-Fluid System in Deepwater Environment in Mexico Helps to Cure Severe Loss of Circulation: A Case History
Authors: Castro Jorge , Solis Luis , Urdaneta Javier , Arreola Victor 
Published: March 2011

Abstract
Loss of circulation during the drilling stage in wellbore construction is a common issue, especially in a wildcat well. However, exploration is required to increase the reserves, and it frequently has to be performed in areas of difficult access and in deeper-water wells.
Loss of circulation can significantly increase the operation cost, delay the drilling program, and can involve risks for the stages or even the well. It usually consumes more resources, such as mud, rig time, logistics, and modifications in the survey, etc. The outcome can be an ineffective use of time during well construction.
A version of this paper was presented at PECOM 2009 in Mexico during the transformation through innovation providing an in-depth view of the current Mexican critical-technology issues. This manuscript focuses on how a severe loss of circulation was treated using a heat-activated, rigid rapid-fluid treatment, restoring full circulation and successfully increasing the window gradient in the first attempt in a deepwater wildcat well in the northern Gulf of Mexico. An engineered solution was proposed for the placement and calculations. It was verified through laboratory tests and in the field. In addition, this paper discusses the results of the application and how it was applied in the next drill stage based on a drill, tack-and-squeeze methodology. This method has become an alternative solution for the operator in this kind of well.
Collapse Prediction Methodology for the Solid Expandable Tubular
Authors: Agata J. , Tsuru E. , Sawamura M. , Asahi H. , Tsugihara H. 
Published: March 2011

Abstract
This paper summarizes an experimental and numerical study aimed at understanding the collapse resistance of expandable tubulars (EXP-T), both before and after expansion, and at constructing a prediction method for post-expanded collapse.
Post-expanded collapse resistance is one of the important properties for EXP-T, and the high-collapse EXP-T is necessary for the realization of expandable tubular monobore wells. Thus, a reliable prediction technique can be useful for casing-design utilizing EXP-T. However, the current collapse formulas widely used are not applicable to post-expanded pipes.
To solve this subject, firstly, full-scale expansion and collapse tests were performed to compare collapse resistance between two materials. Secondly, two prediction methods were validated for post-expanded collapse: finite element analyses (FEA) and the statistic formula used in conventional OCTG.
The test results demonstrated that post-expanded collapse resistance is significantly degraded by the increase in the diameter-to-thickness ratio. There was a large difference in the reduction ratio of the collapse between the conventional and trial material, and the FEA model is capable of evaluating the precise collapse strength of post-expanded pipes by modeling the collapse governing factors. It was also clear that the distribution of residual stress after expansion is opposite to conventional OCTG, although the residual stress deteriorates the collapse resistance after expansion. Moreover, by modifying the definition of the mechanical property of the pipe, the collapse prediction formula is capable of accurately calculating the collapse pressure after expansion. This result is caused by the difference in the shape of stress-strain (S-S) curves between conventional OCTG and post-expanded pipes.
We expect that this research work will contribute to improving our understanding of EXP-T collapse, and will help form the technical basis for the reliability of EXP-T casing design.
Remote Communication Techniques From Surface to Downhole Tools
Authors: Joseph P. , Mendez L. E. , Dolyniuk D. 
Published: March 2011

Abstract
In this age of multizone and multilateral wells, existing technologies are always challenged to achieve desired results. During the drilling and completion phases of a well, surface communication to downhole tools is essential to either orient or activate these tools. As these wells get deeper, extended reach and complex, traditional methods of communication are challenged and stretched to the limit.
This paper will present new remote communication techniques from the surface to the downhole tools. Primary focus while developing this technique was toward downhole completion tools like packers, anchors, and flow- control devices. Two methods of communication will be discussed. The first method described will be communication to the tool using flow-induced signal patterns. The second method will be using signal patterns generated by an acoustic source at the surface. Both methods generate vibration and pressure signals that are received by transducers housed in the downhole tool. These acquired signals are then processed to determine if they match a pattern that is stored in the tool. If it does, then the command is given to activate the tool.
To test these techniques, a new tool was developed and results showed that these methods are viable means of remote communication. It is anticipated that these new techniques will enhance the ease and reliability of setting these tools without adding significant cost.
Conventionally Undrillable Open Fractured Reservoir, Drilled Using Managed Pressure Drilling Technology
Authors: Hamoudi I. , Kartobi K. , Qutob H. , Arnone M. , Torres F. , Barakat N. 
Published: March 2011

Abstract
The Field was discovered in 1960 during the exploration phase, this field is located between the Hassi Messaoud field and Rhourd de Nouss Central Field in the Triassic Basin in Algeria. The field represents many challenges for conventional drilling due to the complexity of the geological structures, one of these is the Hamra Quartzites formation; a gas reservoir sandstone highly tectonically fractured. The drilling history of this formation shows events of total fluid losses leading to gas kicks due to the loss of hydrostatic head in the annulus.
A 6" hole section in NZ-XX well was planned to be drilled under the Constant Bottom Hole Pressure (CBHP) technique, throughout the Gres de Ouargla and the Hamra Quartzites formations; bounding the drilling window by the estimated formation pressure as lower limit, and the fluid losses pressure (hydrostatic pressure of mud used in offset wells) for the upper limit, both estimations were done at the top of the reservoir. The drilling window for Managed Pressure Drilling-MPD was validated by determining the Bottom Hole Pressure where both, an influx from the formation and fluid losses occurred. These values were later used to establish the target Equivalent Circulating Density-ECD to drill the hole accordingly.
The ECD management was achieved by controlling both, the surface back pressure and the annular out-flow; monitored in real time. The Bottom Hole Circulating Pressure-BHCP changes recorded in a Pressure While Drilling-PWD tool, placed in the Bottom Hole Assembly-BHA.
As the drilling progressed, fluid losses were experienced and instantaneously controlled by reducing the ECD. Despite the lower and upper MPD window limits converged, drilling continued managing losses as no open operating range existed. As a contingency for this scenario, switching to the Flow Drilling technique (UBD) was proposed and planned, but due to environmental restrictions, flowing the well while drilling was not possible. The MPD operations in NZ-XX successfully achieved 191 meters of open hole; then TD was called due to a combination of increasing losses – gas influx conditions and increasing risk of total losses in the underlying Hamra faulted structure.
This paper describes in detail the successful MPD application which is considered a start he drilling technology to enhance Nezla field exploitation. Lessons learned and challenges encountered will also be discussed in this paper.
Results of July 15, 2010 IADC Stick-Slip Mitigation Workshop
Authors: Womer K. A. , Torkay D. R. , Villanueva G. , Geehan T. , Brakel J. , Pirovolou D. , Reid D. , Killalea M. 
Published: March 2011

Abstract:
This paper presents the results from a workshop on stick-slip mitigation held in Houston on July 15, 2010. This workshop, sponsored by the IADC ART Future Technology Subcommittee, brought technology leaders and engineers together to discuss issues related to Stick-Slip mitigation. Led by specialists with operating and technology companies, its goal was to educate the industry regarding existing technologies available to address this issue as well as identify the need for possible future technologies. In addition to presenting technical results, the paper describes the unique structure of the workshop: (1) opening, non-commercial presentations wherein the science of stick slip and the business case for its mitigation were reviewed; (2) a series of short presentations by various providers with technologies to identify or mitigate stick-slip; (3) a round table discussion, involving both the presenters and the audience, to assess the effectiveness of these technologies and assess areas where further technology, education, or process improvement is needed. This was all condensed into an afternoon so as to accommodate the demanding schedules of the participants and audience. This workshop is the first of a series of planned workshops to address technology needs which were identified in an industry survey conducted by the IADC Advanced Rig Technology committee last year and reported in SPE 128953.
Real Time Pore Pressure Prediction Using LWD And Borehole Seismic Data Assists In Mitigating Risk On An Appraisal Well Offshore Malaysia
Authors: Ahmed Aqil , Anis Leo , Fey Scott , Hussain Riasat , Rahim Helmi , Tan Boon Hua , Mohaideen Azlan 
Published: March 2011

Abstract
A successful methodology was employed in drilling an appraisal well offshore Malaysia where pressure ramps were expected from the pre-drill geomechanical study. To drill to TD safely, casing point selection and mud weight management were critical during the drilling phase, Both Type 1 and Type 2 overpressure mechanisms were expected to be encountered. (Type 1 is related to undercompaction and Type 2 related to fluid expansion)
Pore pressure prediction has become a vital tool to assist drilling in challenging environments. Traditional LWD measurements like resistivity and sonic are employed but with the advent of seismic while drilling, an extra acoustic measurement is introduced to increase the confidence in pore pressure prediction workflow in real time. Combined with velocity trends extracted from the surface seismic and wireline seismic gives increased confidence in the velocity to pore pressure transforms.
The main challenge was to manage the mud weight in the 8.5 inch hole section where a second pressure ramp was expected but the uncertainties were higher both for the magnitude and depth at which it would occur. The drilling interval for this section was 1968m to 2800m TVDSS. Mud weights were expected to go as high as 16.5 ppg.
The 12.25 inch section was optimized for casing point selection by the use of real time seismic checkshots for accurate time depth conversion.
In the 8.5 inch section two interventions were made.
Using the pore pressure prediction - mud weight was increased above Formation 11 (shale) to avoid a predicted ramp in real time. The intervention was made early enough so that the mud could be weighted up in time.
The second intervention was for TD (Pressure criteria was preset). The Real Time Pore Pressure Prediction indicated pressure at TD would exceed the BOP limit so TD was called earlier at 2680m TVDSS instead of 2800m TVDSS
Pressure predictions were confirmed by a subsequent wireline formation tester run.
By employing the real time pore pressure prediction workflow Petronas were able to safely and successfully drill to TD on a challenging well.
Exploration of the Interaction Between Drill Bit Gauge Profile and Point-The-Bit Rotary Steerable Systems
Authors: Lines L. A. , Larronde M. L. , Stroud D. R. 
Published: March 2011

Abstract
This paper describes an investigation of bit passive gauge profiles for a latest generation point-the-bit Rotary Steerable System (RSS) shown in Figure 1. Using theoretical analyses, a methodology has been developed for exploiting lateral stability afforded by extended passive gauge, without limiting steerability or creating stick-slip or high torque. Results of laboratory testing and field studies are presented, showing a step-change improvement in drilling performance and efficiency.
Full scale laboratory testing and field studies explore the impact of extended passive gauge in maintaining lateral stability. Results show that typically much longer passive gauge length than is common can be applied without adversely affecting steerability or stick-slip. These practical results are fully explained by theoretical analyses that predict critical gauge lengths. The optimum gauge profile is shown to be dependent on hole size and formation type.
For some time; short gauge drill bits have been the fashion, dominating the industry. More recently the importance of extended passive gauge to lateral bit stability has been recognised, but concerns over steerability and torque generation has limited adoption. These misconceptions are likely a consequence of early point-the-bit RSS testing in which incremental increases in gauge length unwittingly produced assemblies close to the critical length/diameter ratio for ‘cock and lock’. Until now, solutions applied have either reduced gauge length or tapered the gauge at the steering system tilt angle -solving the problem at the expense of much of the lateral stability, leaving the drilling assembly vulnerable to undesirable dynamic conditions.