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Are you overpaying $5,333 per day on your well program? If your drilling provider is not maximizing their rig moves with the best processes in the industry-- you may be actually LOSING money by only focusing on the day rate. Check out this example and learn more from Todd Fox at Helmerich & Payne. 📖📚 Dive into our 100+ year history here: https://bit.ly/hpabout REVOLUTIONARY RIG DESIGN. 💪 Read about our award-winning FlexRig® Fleet designed for optimal flexibility, performance and efficiency: https://bit.ly/flexrig-fleet 🎥 Watch our Flex 3 in action: https://bit.ly/flex3-move WANT MORE AUTOMATION? ⏳🔃 Our advanced Rig Floor Automation technology can help you achieve better drilling outcomes: https://bit.ly/rigfloor-automation 🤝TALK TO A RIG SPECIALIST TODAY! Contact our sales team: https://bit.ly/sales-contacts 🦺 WE ACTIVELY C.A.R.E. Our award-winning HSE approach focuses on separating people from hazards through processes, training and technology. https://bit.ly/hse-camp...

Learn More about Rig Floor Automation from H&P: https://www.helmerichpayne.com/drilli... As a leader in unconventional drilling, Helmerich and Payne is proud to present this phase of drilling automation with the Rig Floor Automation package. Focusing on improving connection times, reducing time spent in high risk zones and increasing more consistent execution yields great results for our customers. 🏅The Rig Floor Automation package includes the industry leading HexGrip™ 120 automated floor wrench, custom developed retractable slip lifters and traction control floor mats. The comprehensive package has supported incredible improvements on the rigs they are deployed on. One operator saw a 90% reduction in their manual tong events! 🔗⛓🔗⛓🔗⛓🔗⛓🔗⛓🔗⛓🔗⛓🔗⛓🔗⛓🔗⛓🔗⛓🔗⛓ Case Study: https://bit.ly/RFA-Case-Study Webpage with Ebrochure: https://bit.ly/HP-RFA Contact sales: https://bit.ly/RFA-Sales .

  By utilizing the materials provided herein, the user agrees H&P does not provide or purport to provide any goods, services, or direction regarding the user’s specific work environment. The information included herein is continually under development and is subject to change at any time, therefore users must exercise their own independent judgment to evaluate their use of and reliance on these materials. The implementation of any practices described herein is at user’s own discretion and risk. H&P assumes no liability for any losses, (including, without limitation, incidental, special, punitive, or consequential damages), arising in any manner from user’s reliance on or implementation of the materials or practices included herein. H&P makes no representations or warranties with respect to the accuracy, reliability, sufficiency, or completeness of the materials set forth herein, including, without limitation, any implied warranties of merchantability or fitness for any...

  Geosteering solves for a drill bit's stratigraphic location to optimally guide a wellbore through a target formation. Geosteering solutions focus on correlating a subject well's real time measurements to a type log representative of the stratigraphic column. Traditionally, this is done by matching localized sections of each log with a combination of shifts and stretches applied. This is a single-solution-at-a-time approach where only the best correlation is represented, as determined subjectively by a human or via algorithmic minimization of differences between measurements (Maus et al 2020). A method that considers the full space of possible stratigraphic interpretations and assigns a complexity related correctness likelihood to each would give geosteerers greater confidence in selecting the correct interpretation. This would be a prohibitively large space to explore via traditional optimization and inversion methods, but it is possible through application of a Viterbi algo...

Analysis of low frequency axial drilling dynamics from block velocity input to surface weight on bit (SWOB) or differential pressure outputs, shows significant regional variation. This range in dynamics poses a robustness challenge for automated drilling control systems . Many factors influence drilling dynamics such as pipe stiffness, mud properties, tortuosity, friction, bit design, and BHA geometry . A simple analytic model representing axial drilling dynamics is described and compared to a finite element drilling model and to drilling data. The analytic model shows that axial drilling dynamics may be represented by a first-order transfer function with a time constant dependent on axial stiffness and drillabillity. Reach out to us here for the full tech paper: https://www.helmerichpayne.com/resources/technical-publications/modeling-of-axial-rotary-drilling-dynamics-as-a-step-towards-drilling-automation or contact us here: https://www.helmerichpayne.com/contact .

This paper will present predicted vs. measured wear for six wells that were analysed in the Culzean field , which is a high-pressure, high-temperature (HPHT) gas condensate field located in the central North Sea. The focus rests on the casing wear prediction, monitoring and analysing process and within that, especially on how to make use of offset well data to improve the accuracy of casing wear predictions. The three major inputs to successfully predict casing wear are: Trajectory & tortuosity, wear factor and required rotating operations. All those were calibrated based on field measurements (High-resolution gyro , MFCL (Multi-Finger-Caliper-Log) and automatically recorded rig mechanics data), to improve the prediction quality for the next section and/or well. The simulations were done using an advanced stiff-string model featuring a 3D mesh that distinguishes the influence of different contact type and geometry on the wear groove shape. The " single MFCL interpretation m...

  The hydraulic effects on torque and drag modelling have been thoroughly studied in the past, yet their interpretation still causes a lot of misunderstandings and confusions. Historical models disregard the circulation effects and focus on the fluid mass by employing buoyancy forces based on Archimedes principle. On the other hand, the reference model including the fluid circulation effects, introduced by R. F. Mitchell in the 1990s, consists in computing the forces due to internal and external fluids along the drill-string. These two hydraulic models, after implementation in a true stiff-string 3D model enable then to fairly compare the two approaches in terms of forces applied on the structure. The comparison of this Archimedes formulation with pressure area model gave sensibly the same results for various scenarios, proving the equivalency of the two approaches even with the case of circulating fluid. In addition to the model-to-model comparisons, torque and drag results are ...

Three-mile laterals have become more common over the last five years of onshore US drilling . They are especially commonplace in the Appalachian and Permian basins and are used to overcome limited surface access for drill pads and for economic reasons. These long laterals pose significant wellbore positioning and anti-collision challenges. Horizontal position error grows at 2% (or more) of the lateral length per degree of wellbore azimuth error. This work addresses these wellbore positioning challenges with a new and significant improvement in magnetic field determination . With this procedure, multi-well pads with tightly spaced three-mile laterals can be drilled without compromising anti-collision standards or horizontal placement goals. For more challenging pad designs, such as three-mile laterals, a new method has been developed to combine an IFR 1 magnetic model with a near-well magnetic theodolite measurement to build a more precise magnetic model and positioning tool code. Sp...