Истории Rigcontractoroilandgas

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.

Viterbi is an established algorithm with many applications, but the splitting of stratigraphic mappings into a Bayesian state space and application of Viterbi is novel and allows for efficient, probabilistic solution-finding. The whole space of possible solutions can be considered, and implicitly gives solution likelihoods. The technique also accounts for the complexity of produced solutions. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/how-a-bayesian-approach-can-overcome-noisy-data-and-interpretation-ambiguity-in-automated-geosteering or contact 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.

When we talk about Actively C.A.R.E.™ (controlling and removing exposures), that can often be interpreted as only focusing on exposures that can harm people on the job. Actively C.A.R.E. is more than that. It encompasses how we approach our relationships, the way we work and the future we hope to leave behind. In this months' newsletter we are specifically focusing on what we can do to care for our environment.

Once the tasks of laying down casing and drill pipe were completed, the derrick was then lowered and replaced. The crew was cleared to resume drilling ahead. "Yeah, that was April 19. Then on May 11, we had another one, right across the highway from us. You could chunk a rock at it." Drilling in remote locations - whether in the middle of the ocean, the middle of a rainforest, or the middle of rural Oklahoma - brings its own set of issues when inclement weather takes place. Multiple methods of monitoring exist in the event that systems are unavailable. The Starlink satellite system on all H&P rigs, storm radios, high tech rig phones, and even a basic antenna for local channels all ensure accurate and up to date weather information is available. Read out the full HSE News from here: https://bit.ly/3vsbhSH or you can also download the article from here: https://bit.ly/3U1Pzhu. Contact us to know more about our HSE News: https://bit.ly/452JYdl.

A multi-stage penalized procedure is developed that optimizes this alignment map to minimize a misfit function, while taking the prior knowledge into consideration. Read out the tech paper in detail by visiting here: https://www.helmerichpayne.com/resources/technical-publications/improved-typelog-alignment-for-automated-geosteering-using-multi-stage-penalized-optimization or you can reach out to us directly here: https://www.helmerichpayne.com/contact.

The configurable and consistent bit engagement enabled through H&P's FlexDrill software helped ensure optimal contact with the formation, resulting in a 61% average rate of penetration (ROP) improvement. Additionally, by reducing bit and BHA torsional and lateral vibration through the H&P Autodriller control system, fewer BHAs were required to drill the well. Overall, H&P helped the operator reduce BHA change count by 9%, which meant one fewer BHA used in an area of especially hard drilling. They saw an 11-day improvement over the previous well, which equates to a 26% time savings. To know more in detail, visit us at: https://www.helmerichpayne.com/resources/case-studies/61-average-rop-improvement-reduces-operators-time-to-target or you can also download the pdf of the same from here: https://www.helmerichpayne.com/media/case-studies/61-average-ROP-improvement-reduces-operator's-time-to-target.pdf. Contact us here to know more: https://www.helmerichpayne.com/contact.

Improve excess engine hour precision • Maintain all 2023 rigs under 30% and increase targeted efforts for rigs operating above 50% excess engine hours. • Reduce fleet vehicle idle times by 25% • Reduce volume of spills per 1000ft drilled by 15% Download the Article from here: https://www.helmerichpayne.com/media/product-highlights/Improving-Lives-Through-Affordable-and-Responsible-Energy.pdf. Know More about H&P - https://www.helmerichpayne.com/our-approach/why. Contact us from 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.

Friday night lights... tailgating Saturdays... and of course, armchair quarterbacking Sundays. It's the most wonderful time of the year! Now, imagine if your favorite football team had to play a championship game with the same gear they used a century ago. The game would be drastically different-less safe, less efficient, and much more dangerous. Similarly, the evolution of personal protective equipment (PPE) in the drilling industry has transformed its safety and effectiveness over the years. Just as football gear has advanced from simple leather helmets to sophisticated, high-tech armor, PPE has undergone significant changes to better protect our most valuable asset: our people.

We know that energy exposures provide a significant amount of threat to a worker on a drilling rig. We also know it is important to have strong processes in place to help mitigate our exposure to energy as we Actively C.A.R.E. for ourselves and others. Mitigating these risks requires the development and refinement of robust processes and procedures, with worker input being key to ensure effectiveness and adherence. As the industry continues to evolve, so too must our commitment to safety, reflected in evolving processes, policies, and training practices.

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.

For the baseline scenario, low probabilities of collision imply that extensive use of ranging is required for a successful operation. Positional uncertainty reduction techniques and multiple target intervals can greatly increase the collision probability and reduce the need for ranging. Of importance to increasing the probability of successful interception are techniques that maximize the uncertainty reduction along a single axis (e.g. the vertical plane).

With directional drilling in today's market, well placement is of ever-increasing importance in the process of successfully drilling a well. Well placement by Measurements While Drilling (MWD) uses the direction of the Earth's gravity and magnetic field as a natural reference frame. For years, the industry standard used low resolution global models for this reference, such as the International Geomagnetic Reference Field (IGRF-13). These models only captured a fraction of the true complexity of the Earth's magnetic field, leading to inaccurate MWD corrections and consequently large uncertainties in the wellbore's final placement.

AutoSlide technology was used for 88.5% of the lateral section. Significant increases were seen in both lateral onbottom rotating rate of penetration (ROP) and lateral slide ROP when compared to the previous 10-well average values, indicating to a significant improvement of 132% and 53%. These improvements translated to less days on well, which not only saves money, but also may allow for more wells to be drilled over the course of a year. Based on this success, the operator has added technology packages, including AutoSlide technology, to additional rigs. Read out the full case study here: https://www.helmerichpayne.com/resources/case-studies/integrated-drilling-solutions-break-records-while-reducing-operators-time-to-target or you can reach out to us here: https://www.helmerichpayne.com/contact.

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.

Continuous real-time updating of the bit position is one of the many critical analysis steps that can be automated, driving steering decisions. The practice of accurately predicting bit position and trajectory is a skill that is artfully developed by expert directional drillers over many years. To demonstrate the value of partial automation, a specific example is presented where the continuous calculation of the real-time bit position and its trajectory is fully automated, showing that the analysis and decision-making performed by the automated system is faster and more accurate than performed by human directional drillers.

Advanced modeling and simulations optimize drilling operations and increase well integrity by providing in-depth analysis for well planning, well integrity, BHA and bit selection, and drillstring modeling. Know more about DRILLSCAN ENGINEERING SOFTWARE - https://www.helmerichpayne.com/technologies/drillscan. Contact Us Today - https://www.helmerichpayne.com/contact/contact-sales.

The dynamics is then calculated by applying a time-integration scheme. The dynamic model is applied to a real case of a quasi-vertical well with field measurements of downhole vibrations along with surface data. Numerical simulations are carried on a drilling assembly of several kilometers' length. The novelty of the proposed dynamics model is its ability to consider a realistic geometry of drilling assembly in 3D curved wells with fluid flows, and to give a complete study of the coupling phenomena between axial, torsional, and lateral vibrations. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/nonlinear-dynamics-of-a-drillstring-immersed-in-a-3d-curved-well-simulations-and-experiments or you can also contact us here: https://www.helmerichpayne.com/contact.