#automateddirectionaldrilling

H&P GLOBAL GEOMAGNETIC MODELS Effortless survey management solutions by the proven industry leader Reducing Uncertainty in Wellbore Placement 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. Large uncertainties in the final wellbore placement lead to many issues in the life cycle of the well. Improper placement can lead to a loss in reservoir production or collision issues with adjacent wells. To help reduce these uncertainties and help alleviate the issues posed by them, H&P recognized the need for higher resolution models of the Earth’s magnetic field. Allowing for more accurate MWD corrections while drilling the well. To accomplish this, H&P offers a full suite of services to reduce this uncertainty so every customer has an option that meets their needs. One of those is highly accurate global geomagnetic reference models. Global Geomagnetic Reference Models H&P recognized the need for more accurate global geomagnetic reference models versus the industry standard. We also realize not every client has the same needs or budget. With that in mind, we produce the MagVAR Standard Definition Global Geomagnetic Model (MVSD) and the MagVAR High Definition Global Geomagnetic Model (MVHD). The MVSD is a spherical harmonic model of the Earth’s main field built from global magnetic data collected via satellites. H&P’s modeling captures the Earth’s main field and crustal anomalies as small as 300 km in size, making the MVSD a significant improvement over the industry standard IGRF model. The MVSD meets the conditions of the MWD tool code. The MVHD is an ellipsoidal harmonic model built from global satellite magnetic data plus near-surface magnetic data sets. This allows the MVHD to capture the Earth’s main field and crustal anomalies down to a resolution of 40 km. The increased resolution of the MVHD is a great solution compared to other models in the industry. The MVHD will satisfy the conditions of the MWD+HRGM tool code. The MVSD and MVHD models are updated annually to capture the secular changes to the magnetic field and implement modeling improvements. REDUCE THE ELLIPSES OF UNCERTAINTY By integrating the MVSD or MVHD models into your workflow you will reduce the Ellipses of Uncertainty (EOU). Our software now has the ability to use the MWD or MWD+HRGM tool codes when planning and drilling a well. Benefits include increased separation factors when anticollision planning, reservoir production and safety. EASE OF USE H&P delivers each model with our global calculator. A user-friendly interface used to extract single or multiple points along a well path file from either MVSD or MVHD at your chosen date. H&P can also make the models available as a plug-in for your well planning or directional drilling software of choice, making this a seamless integration to your workflow. TOOL CODE REFERENCE MODEL APPROX EOU± MWD + IGRF IGRF +10% MWD SD 0 % (STANDARD) MWD + HRGM HD -10% PROOF IN THE FLIGHT LINE At H&P, we compare our MVSD and MVHD models to proprietary high-resolution aeromagnetic surveys. By doing this, we provide proof in our modeling. These surveys represent Earth’s true magnetic field. As seen above, the MVSD model captures the overall trend of the Earth’s main field. The higher resolution MVHD model begins to include some of the high-resolution features in the Earth’s magnetic field generated by the crustal component. ADDITIONAL ADD ON SERVICES At H&P, we also offer add on services that can further reduce uncertainty when using MVSD or MVHD. • Advanced MWD Analytics: method for reducing MWD survey error through least squares regression techniques • Sag: method of correcting bottom hole assembly (BHA) Sag misalignment • IFR Pad Solution (IFR-PS): IFR-1 level corrections based off local correction applied to MVHD from groundshots taken on pad CONTACT US TODAY AT +1 303 539 5339 OR VISIT https://www.helmerichpayne.com/contact INDUSTRY EXPERTS ARE ALWAYS A PHONE CALL AWAY TO ANSWER ANY MVSD OR MVHD QUESTIONS YOU HAVE. Download the full product literature from here: https://www.helmerichpayne.com/media/product-literature/HP_OneSheet_Global_Models_v2.pdf #helmerichandpayne #drillingtechnology #rigcontractoroilandgas #drillingautomation #drillingrigcontractoroilandgas #automateddirectionaldrilling

FlexB2D® Technology - achieve configurable and consistent bit AND BHA engagement 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. • Reduce torsional and lateral vibration • Reduce bit and BHA damage • Cut unplanned trips • Decrease transition time from connection to drilling • Automated zeroing ensure accuracy and consistency • Automated staging to 9 operator defined drilling setpoints ensure consistent execution Repeatable Results Enable Optimal Outcomes Reduces Risk · Lowers risk of damaging downhole tools by reengaging the bit in a controlled and repeatable manner Lowers Total Cost of Operations · Less costly bit and BHA issues · Improved consistency drives lower cost per foot Accelerates Well Programs · Lower rotary to on-bottom time averages contribute to time savings in overall cycle time CONTACT US For more information on how FlexB2D® technology can help you achieve better drilling outcomes, contact an H&P sales representative today or contact us through our website at helmerichpayne.com/contact. Download the full product literature from here: https://www.helmerichpayne.com/media/product-literature/FactSheet_HPIDC-CS05_FlexB2D_Overview_V7.pdf #helmerichandpayne #drillingtechnology #rigcontractoroilandgas #drillingautomation #drillingrigcontractoroilandgas #automateddirectionaldrilling

“Blue 42! Blue 42! Set!” The Evolution of PPE in the Drilling Industry 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. In the high-stakes game of drilling operations, PPE can be considered our “prevent defense” against various risks and exposures. From the protective helmets that guard against falling objects to the flame-resistant clothing that shields workers from intense heat, each piece of PPE plays a crucial role in minimizing injuries and helping ensure that every worker can stay in the game and make it home safely to their families. So, let’s suit up, lace up your cleats (or steel-toed boots in our case) and get ready to dive into the history and game-changing advancements in PPE that are making a significant impact on safety in the drilling industry. Hard Hats: From Canvas to Polyethylene The story of hard hats begins with the Hard-Boiled Hat from Bullard, crafted from steamed canvas, glue, leather, and black paint. This early version, named from its steam-based manufacturing process, was a rudimentary precursor to the hard hats we have today. Over the decades, hard hat compositions have changed, manufactured from aluminum, fiberglass, thermoplastics, and currently polyethylene plastics, which are both durable and lightweight. Eye Protection: From Glass to Polycarbonate In the mid-20th century, eye protection primarily consisted of glass or hard resin lenses, which, while protective, were quite brittle, presenting a secondary hazard. The rigid design of early eyewear was heavy, and not particularly comfortable or aesthetically pleasing. A turning point came in 1979 when the American National Standards Institute (ANSI) revised its standards, allowing for more varied designs, as long as they passed impact tests. Around the same time, polycarbonate – a lightweight, highly impact-resistant material – was introduced. From the 1980s up to present day, polycarbonate lenses became the standard, offering superior protection without the added weight. Continued innovations and improvements in durability, comfort, and design have significantly reduced the risk of eye injuries, transforming eye protection from cumbersome to cutting-edge. Gloves: From Leather to Impact Resistant Working in the field requires hand use nearly constantly, and the evolution of gloves reflects the diverse hazards of the modern workplace. The first patented work glove dates back to 1896, with early designs primarily featuring leather for basic protection. As workplace hazards became more varied, gloves evolved to include materials and designs tailored to specific risks. Chemical-resistant gloves are used to protect workers from hazardous chemicals. Heat-resistant gloves are used to protect workers from high temperatures and open flames, and electrician gloves are designed to protect workers from electric shock. Advances in materials have led to impact, cut, and puncture-resistant gloves that greatly reduce the severity of injuries. Modern gloves not only protect but also provide improved dexterity and comfort for extended use. Fall Protection: From Belts to Harnesses As working at heights became more common in the oilfield, fall protection equipment became necessary. The introduction of fall protection began with body belts and lanyards in the 1970s and 80s. Read out the full HSE News here: https://www.helmerichpayne.com/blue-42blue-42-setthe-evolution-of-ppe-in-the-drilling-industry. Download the article of the same from here: https://www.helmerichpayne.com/media/product-highlights/Evolution-of-PPE_082124-5.pdf. And contact us to get in touch with us: https://www.helmerichpayne.com/contact. #helmerichandpayne #drillingtechnology #rigcontractoroilandgas #drillingautomation #drillingrigcontractoroilandgas #automateddirectionaldrilling

Autodriller®PRO Control SYSTEM AN INDUSTRY-FIRST THAT ENABLES SMOOTH DRILLING USING DIFFERENTIAL PRESSURE H&P’s advanced drawworks control system smoothly controls block velocity while regulating inputs from differential pressure, torque and/or weight on bit (WOB). The Autodriller® Pro control system accomplishes an industry-first by seamlessly transferring to/from WOB and differential pressure, while maintaining smooth drilling that doesn’t require changing gain settings at the drillers console. A CONTROL SYSTEM THAT KNOWS WHAT IS IMPORTANT, WHEN IT MATTERS MOST. By design, this system automatically regulates to the parameter most in control at the time (differential pressure, weight on bit, and torque) in order to maintain smooth block velocity to improve consistent bit/rock engagement. Smooth block velocity results in less axial oscillations from surface, providing a higher rate of penetration (ROP) and improved bit and downhole tool reliability. OUTCOMES Compare the Performance › Average Rotating ROP improved 21%, 31% in Int, lateral section respectively. › Average time saved drilling while rotating 16.6 hours (~$30k/well). › Total on bottom-time reduced by 17%. Autodriller® Pro control system Observations at the Same Depth interval › Higher differential pressure maintained with the Autodriller® Pro control system—contributing to higher ROP. › Payout stability observed with reduced variation. › ROP limit is disabled on the Autodriller® Pro control system with ROP overshoot observed on 4 of 5 stands. CONTACT US For more information on how our Drilling Engineering Services can help you achieve better drilling outcomes, contact an H&P sales representative today or contact us through our website at helmerichpayne.com/contact. It’s time to follow through on your drilling performance potential. Download the PDF from here: https://www.helmerichpayne.com/media/product-literature/Autodriller-Pro-Control-System.pdf. To know more about the Autodriller® Pro control system, watch this full video: https://www.youtube.com/watch?v=ai9boL8hLAA. #drillingautomation #rigcontractoroilandgas #automateddirectionaldrilling #helmerichandpayne #drillingwithtechnology

FULLY AUTOMATED DIRECTIONAL DRILLING FOR CONSISTENCY AND IMPROVED PERFORMANCE | Helmerich and Payne With the high rates of penetration achieved by today’s drilling contractors, directional drillers have little time to make optimal steering decisions in a continually changing environment. Even when proper directional drilling decisions have been made, flawless execution of each decision can be difficult to perform.   Performance related to drilling speed, drilling accuracy, and tortuosity are often inconsistent and greatly determined by the experience, skills, and even the current state of mind of both the directional driller and the driller. These factors lead to increased drilling and lifting costs along with wells having inconsistent hydrocarbon production potential. Watch out our video to know more about H&P Drilling Performance: https://youtu.be/Ee4BIOjTqWM?si=lusNyZpQe4vCKKcB.   Today, directional drilling tasks are increasingly automated to deliver more consistent and improved performance in the field. Before automation can control the physical equipment on the rig, a foundation built upon automated decision-making is critical. An automated bit guidance system provides this foundation and has drilled more than 800 wells successfully across all of the major unconventional plays in North America.   Building upon the decision-making foundation, the next level of automation executes the steering decisions from the bit guidance system automatically. Slide sequences are initiated, executed, and terminated by directly linking the bit guidance system with the rig’s existing control system. Read out the full tech paper by visiting us here: https://www.helmerichpayne.com/resources/technical-publications/fully-automated-directional-drilling-for-consistency-and-improved-performance or you can also access the PDF of the same from here: https://www.helmerichpayne.com/media/technical-publications/Fully-Automated-Directional-Drilling-for-Consistency-and-Improved-Performance.pdf. Want to know more about us? Then reach out to us at: https://www.helmerichpayne.com/contact. #automateddirectionaldrilling #improvedperformance #helmerichandpayne #techpaper

REAL-TIME DIRECTIONAL SURVEY QUALITY IMPROVEMENT USING WEB-BASED TECHNOLOGIES Optimal wellbore placement and collision avoidance requires accurate real-time steering of directional wells. Uncertainties in the wellbore position are accounted for by industry standard error models. However, these error models are only valid if the directional surveys are quality controlled and gross error is prevented by appropriate procedures. Particularly effective quality control is achieved by independent validation. A novel real-time web application was developed for the transfer of directional survey data between the rig site and a remote operations center. Surveying professionals at the rig site upload or import survey data into the web application in real-time. The survey measurements are then automatically validated through independent quality checks to identify gross error. Remote survey analysts can access the pre-qualified survey data and evaluate it for systematic or random error that would indicate non-compliance with the instrument performance model. Surveys can also be corrected in real-time when systematic error is identified and provided back to the rig site personnel for accurate steering and wellbore placement. This web service has been implemented and refined on over 50 rigs in North America. Examples for common types of errors that were prevented and/or corrected are incorrect magnetic declination, wrong north reference, excessive drillstring interference, poor instrument calibration, sensors misaligned with the wellbore and incorrect survey order. To know more, read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/real-time-directional-survey-quality-improvement-using-web-based-technologies or access the PDF of the tech paper from here: https://www.helmerichpayne.com/media/technical-publications/IPTC-Bangkok-2016.pdf. Contact us to know more: https://www.helmerichpayne.com/contact. We are a drilling rig company in oil and gas sector. We provide automated drilling solutions along with safety, contact us to know more! #rigcontractoroilandgas #drillingtechnology #helmerichandpayne #drillingautomation #drillingrigcontractoroilandgas #automateddirectionaldrilling

MITIGATING AND UNDERSTANDING STICK-SLIP IN UNCONVENTIONAL WELLS Stick-slip is still present in most of the wells drilled today, especially in unconventional wells. Friction is an inevitable and important force along the long lateral section, but it contributes to many types of dysfunctions that lead to drilling inefficiency. Stick-slip is caused mainly by rotational friction induced along the drillstring, from the drill bit cutting the rock formation to the bottom hole assembly and drill pipe that contact the well bore. In the past, much attention has been given the cutting action of polycrystalline diamond compact (PDC) bits to explain and mitigate stickslip, without much emphasis on the frictional torque. However, it is important to understand that the torque generated on the remaining drillstring accounts for most of the total torque at surface. This paper presents a case study on an unconventional well where stick-slip modeling was used to explain and understand stick-slip vibrations with or without the presence of active control systems at surface. First, the stick-slip model, including a PDC bit law friction and accurate contact forces calculation along the drillstring and mud damping effect is fully described, with all necessary and field parameters needed. Then, it explains the process to reproduce and calibrate downhole and surface torque, using a sensitivity analysis showing the most important parameters that affect stick-slip results. The results reinforce the importance of drilling parameters, such as the weight on bit and associated torque on bit that define the bit aggressiveness and are key in controlling or mitigating stick-slip vibration. In addition, these results show the significance of string friction along the drill pipe. Next, the use of a downhole instrumented sub, along with wire drillpipe technology, enables a full comparison of the results of the model with downhole and surface data. Last, the affect of other parameters, such as friction coefficient and mud damping, are discussed. Interesting, right? Know more about us here: https://www.helmerichpayne.com/resources/technical-publications/mitigating-and-understanding-stick-slip-in-unconventional-wells or contact us at: https://www.helmerichpayne.com/contact. Want to know more about us? Reach out here to download the full tech paper: https://bit.ly/48ynXVD. We are an oil and gas company that focuses on safety provides you with drilling rig and drilling automation to ease your production process. #rigcontractoroilandgas #drillingtechnology #helmerichandpayne #drillingautomation #drillingrigcontractoroilandgas #automateddirectionaldrilling #drillingrigcontractor

USING ALUMINUM DRILL PIPE WITH AXIAL OSCILLATION TOOLS TO SIGNIFICANTLY IMPROVE DRILLING PERFORMANCE Aluminum drill pipe has already been proven as a viable alternative to steel drill pipe when drilling long horizontal wells thanks to its lighter weight that does not compromise resistance to yield and buckling. At the same time, the development of unconventional wells has seen the deployment of numerous technologies to further improve the performance and increase the lateral section to reduce costs. An operator has recently and successfully tested a new aluminum drill pipe with an axial oscillation tool to push further the limits of the drilling system. This paper presents the key findings of the case study using a mixed aluminum-steel string combined with an axial oscillation tool. First, the innovative drill pipe design is presented, followed by lessons learned during rig operations regarding pipe handling practices, rig compatibility and pipe inspection. Then, results of the drilling simulations performed during the well planning phase are presented. This modeling led to an optimum drill string design associating the steerable mud motor assembly, aluminum drill pipe, axial oscillation tool and steel drill pipe. The number and placement of aluminum drill pipe along the string was key to reducing friction and improving weight transfer between the bit and the axial oscillation tool. Want to know more about us? Read out the full article here: https://www.helmerichpayne.com/resources/technical-publications/using-aluminum-drill-pipe-with-axial-oscillation-tools-to-significantly-improve-drilling-performance or you can also reach out to us here: https://www.helmerichpayne.com/contact. You can access the full tech paper from here: https://bit.ly/3T20wzr. Reach out to us, we are a drilling rig and automation company that you are looking for!! #rigcontractoroilandgas #drillingtechnology #helmerichandpayne #drillingautomation #drillingrigcontractoroilandgas #automateddirectionaldrilling #drillingrigcontractor

LEARNING CURVE BENEFITS RESULTING FROM THE USE OF A UNIQUE BHA DIRECTIONAL BEHAVIOR DRILLING PERFORMANCES POST-ANALYSIS With the current market’s high prices for drilling units and sophisticated directional and formation assessment services, low systems reliability or poor directional performance in the execution of complex wells (ERD, HPHT, Deep Water applications) can spell costly Non Productive Time (NPT) for operators. Over the past two decades, many Bottom Hole Assembly (BHA) models have been developed to address the directional performance issue, but their application in an operational environment has generally failed for lack of strong associated BHA analysis methodologies. This paper presents a unique automated methodology for Post Analysis of BHA directional behavior. It is based on modern 3D analytical models, combining BHA, BIT and formation effects with highly flexible data management. Implemented in user-friendly BHA management software, it can be used to define a BHA run segmentation and to determine the influence of the BHA settings in particular geological formation blocks. The Post Analysis clearly displays the final results of the BHA (objectives and performances versus prediction window), highlighting any problematic intervals drilled. 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. #rigcontractoroilandgas #drillingtechnology #helmerichandpayne #drillingautomation #drillingrigcontractoroilandgas #automateddirectionaldrilling

NONLINEAR DYNAMICS OF A DRILLSTRING IMMERSED IN A 3D CURVED WELL, SIMULATIONS AND EXPERIMENTS During drilling operations, the bit-rock and drillstring-wellbore contacts with stick-slip phenomena, fluid structure interaction, and mass unbalances distributed along the drillstring yield nonlinear dynamics coupling axial, torsional, and lateral vibrations. Excessive and uncontrolled vibrations may induce drilling equipment damage due to fatigue, cracking, and ruptures. Understanding and predicting the drilling dynamics become necessary to avoid those harmful vibrations. The drillstring dynamics is modelled in the time domain using the beam finite element method. The contact between the drillsting and borehole is accounted for using radial elastic stops and the fluid effect on the drillstring dynamics is considered by two models. The initial position is obtained from a static equilibrium computation that takes into account the drillstring pre-load. 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. #rigcontractoroilandgas #drillingtechnology #helmerichandpayne #drillingautomation #drillingrigcontractoroilandgas #automateddirectionaldrilling