Drillingtechnology Stories

Directional surveys acquired by Measurement While Drilling (MWD) are subject to many errors that are not easily recognized by traditional Quality Control (QC) procedures. This commonly leads to inaccurate wellbore placement and greater positional uncertainty. Common sources of MWD survey error are inaccurate geomagnetic references, localized distortions in the natural magnetic field, poor instrument calibration, random sensor noise, magnetic mud, and human error. Often times, such errors go unrecognized due to limitations in traditional single-station QC tests. This is a significant problem because wellbore collision avoidance, geological modeling, and reservoir drainage are all greatly affected by wellbore placement accuracy. Fortunately, most sources of MWD error can now easily be identified and corrected through implementation of robust independent survey quality control processes. By using web-based systems to facilitate this process, drillers can benefit from the most powerful quality assurance practices which can be standardized across the industry regardless of service provider or vendor specific technologies.

The Coaching Guide originated in 2018 as part of a campaign to equip our Drilling Superintendents and HSE staff with additional tools and skills for coaching employees in the field. Recognizing the diverse skill sets among supervisors and managers, we aimed to support the development of these skills and provide a reference guide. Since its release, the guide has undergone updates to align with our core values and behaviors. Presently, we distribute these guides to new managers and employees seeking to enhance their people leadership skills. By sharing this, we hope it can serve as an additional resource to empower your own leaders. Safety is personal and it's our job to Actively C.A.R.E. for one another.

Staging drilling set points after tagging bottom is often inconsistent and can cause drilling dysfunction. H&P has transformed this common multi-step task into an automated and configurable process with FlexB2D® technology. FlexB2D technology performs automated zeroing of the weight on bit (WOB) and differential pressure set points and helps ensure proper contact with the formation. This allows for configurable and consistent bit engagement, reducing bit and BHA torsional and lateral vibrations.

These analyses can constitute guidelines about stabilizer design to minimize vibrations. The novelty of this work is to introduce the geometry details of the stabilizers in the time domain dynamics to differentiate designs in terms of likelihood to trigger vibrations. Reach out to us to read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/detailed-dynamics-modeling-helps-to-assess-the-effect-of-stabilizer-design-on-drillstring-vibrations or you can directly reach out to us here: https://www.helmerichpayne.com/contact.

Correctly evaluating the risk of BHA, casing and/or completion strings getting stuck or locked-up when RIH can ultimately provide a template for ultimate reduction of non-productive time (NPT). Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/rss-and-motor-directional-analysis-modelling-the-effect-of-local-doglegs-on-rih-of-completions-and-casing or you can also reach out to us here: https://www.helmerichpayne.com/contact.

SKILLED ENGINEERS ENHANCE THE WELL DELIVERY PROCESS, WHILE MEETING SAFETY AND REGULATORY REQUIREMENTS Helmerich & Payne's Advanced Well Engineering team offers a comprehensive suite of drilling engineering services designed to support a range of energy projects, including those within the Oil & Gas and Geothermal sectors. The Well Delivery service covers the entire well lifecycle, of existing wells, culminating in the plug and abandonment process. THE WELL DELIVERY SERVICE PROVIDES A COMPREHENSIVE SOLUTION TO SUPPORT YOUR DRILLING ENGINEERING PROJECT AND HELP ENSURE THEIR SUCCESSFUL REALIZATION.

Our Bit Guidance System makes intelligent decisions based on economics, helping lower drilling costs while increasing production. The AutoSlide® automated drilling platform responds by autonomously executing slides that minimize tortuosity and sliding footage with increased precision. This combination simultaneously delivers better ROP and wellbore quality with continuous economic impact. Download the original pdf from here: https://bit.ly/3rrhSuk. Contact us to know more: https://bit.ly/452JYdl.

Viable interpretations are simultaneously visualized in real time as paths on a novel stratigraphic misfit heat map, where they may be corroborated against valleys of minimal misfit between the subject and reference data. The user can guide the interpretation by setting control points on the heat map which the automated solutions must respect. Read out the full publication here: https://bit.ly/44GMRAh or you can also access the technical paper by visiting here: https://bit.ly/44EVPhi. Contact us here to reach out to us: https://www.helmerichpayne.com/contact.

The hybrid AMV offers distinct advantages for geomagnetic data collection in offshore environments. The low cost compared to a seaborne or airborne vehicle allows AMVs to be deployed in tandem and collect data repeatedly over predefined areas, yielding accurate measurements to determine the disturbance and crustal magnetic fields. Use of the AMV solves the long-standing problem of how to accurately map the previously unknown geomagnetic reference field in offshore locations. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/using-hybrid-propulsion-autonomous-marine-vehicles-to-better-characterize-geomagnetic-fields-offshore or you can also reach out to us here: https://www.helmerichpayne.com/contact.

This paper describes some of the challenges to understanding and ultimately automating drilling processes using models. Examples of models used to solve industry problems are torque and drag, stick slip, surge and swab, drillstring dynamics, and many more. Models may be data-driven, or physics based, steady state or dynamic, high fidelity or reduced order for execution speed and clarity. To learn from a high-fidelity model, data must be collected and fed to the model and parameters estimated to reproduce the behavior of interest.

The use of time-domain modeling to jointly characterize the behavior of downhole axial and surface oscillation tools introduced in this work allows a better understanding of the coupling between the two tools. This work provides an opportunity to increase the extent of the lateral sections without impairing the wellbore quality. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/combining-downhole-axial-and-surface-oscillation-tools-what-are-the-consequences-on-tool-face-control-performance or you can contact us here: https://www.helmerichpayne.com/contact.

Already, the methodology has solved challenging directional performances issues, generating significant savings and optimizing the learning curve process. The model is also run at the well Pre Engineering stage to check BHA design proposals by making multiple sensitivity analyses and by fine-tuning solutions to the operational context. Finally, in an industry with high personnel turnover, the software's global data management system ensures good capitalization of know-how and ongoing learning curve benefits. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/learning-curve-benefits-resulting-from-the-use-of-a-unique-bha-directional-behavior-drilling-performances-post-analysis or you can also contact us here: https://www.helmerichpayne.com/contact.

A sensitivity analysis was then conducted on several BHA types and lengths, considering different boundary conditions in vertical and horizontal wells. Directional models are found to be reasonably unsensitive to the choice of the effective length because they are based on steady-state computations, but the same cannot be stated for dynamics. This study developed a more robust approach to estimate properly the effective length for lateral vibrations, an essential for BHA resonance. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/to-what-extent-can-the-notion-of-an-effective-length-be-reliable-to-assess-the-bha-lateral-behavior or you can also download the pdf from here: https://www.helmerichpayne.com/media/technical-publications/SPE-217755-MS.pdf. Contact us to know more: https://www.helmerichpayne.com/contact.

This work is novel because it combines a ground based, near-well, magnetic measurement with an airborne derived IFR-1 model. This allows for a greater reduction in positioning uncertainty than has been available in the past. The application of this method to three mile laterals is also new and has a profound impact on being able to plan optimally spaced wells and avoiding collisions. Read out here the full tech paper: https://www.helmerichpayne.com/resources/technical-publications/drilling-three-mile-laterals-tighter-and-safer-with-a-new-magnetic-reference-technique or you can also contact us here: https://www.helmerichpayne.com/contact.

The drilling industry faces challenges when it comes to implementing physics-based decisions in real-time, resulting in missed opportunities to improve drilling performance and maximize value. Helmerich & Payne's Advanced Well Engineering Real-Time Advisory service bridges the gap and helps deliver the highest possible value throughout the entire well cycle.

This paper should provide help to engineers who seek to improve the accuracy of casing wear prediction and hence improve casing wear management. It presents a new way of anticipating tortuosity based on offset well data and it offers a suggestion on how to deal with MFCL measurement error during wear factor calibration and wear prediction. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/casing-wear-prediction-monitoring-analysis-and-management-in-the-culzean-field or you can also reach out to us here: https://www.helmerichpayne.com/contact.

After two years of testing the recovery control system internally, there were no undetected stalls, no false detections, and no unplanned trips due to motor stall, displaying detailed accuracy. The recovery control complements the process control, limit control, and manual control components of the automation control system to drill a stand effectively and consistently. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/closing-the-loop-in-automated-control-systems or you can access the PDF from here: https://www.helmerichpayne.com/media/technical-publications/Recovery-Control-Closing-the-Loop-in-Automated-Control-Systems.pdf. Contact us to know more: https://www.helmerichpayne.com/contact.

Positional uncertainty can be modelled by 3-D EOUs at each survey point in the well path, representing a statistical distribution of where the actual survey may exist. EOUs are computed from tool codes using anti-collision software. ISCWSA's Operator's Wellbore Survey Group has published a consolidated set of tool codes to represent most surveying methodologies. Read out the full technical paper here: https://www.helmerichpayne.com/resources/technical-publications/drilling-technology-optimizes-lateral-spacing or you can also download the PDF of the same from here: https://www.helmerichpayne.com/media/technical-publications/AOGR-April-2017_0.pdf. Contact us to know more: https://www.helmerichpayne.com/contact.

Watch the full video to know more about this technology: https://www.youtube.com/watch?v=ai9boL8hLAA A CONTROL SYSTEM THAT KNOWS WHAT'S IMPORTANT, WHEN IT MATTERS MOST AUTODRILLER PRO CONTROL SYSTEM Autodriller pro control system removes human variability and enhances drilling performance Through sequenced collaboration between H&P drilling technologies, H&P can help reduce human variability and provide game changing drilling performance solutions with an advanced autodriller control system. Traditional autodriller systems require manual gain adjustments that can cause variable results. A related issue associated with gains that are either set too high manually, or with a semi-fixed gain system, can result in block velocity variability that negatively impacts rate of penetration (ROP), and in some cases bit life that results in additional trips with time, fuel, and emissions impacts.