Drillingrigcontractor Stories

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!!

What goes up... must come down Dropped objects don't just include large objects like tubulars. As rig crews complete routine mast maintenance and tools are not recorded properly, they can get left at heights. Rough drilling or even a gust of wind can cause these items to fall back down to the rig floor or the ground, with the potential to unexpectedly injure someone. Processes that help us ask, "What if?" Our focus on the control and removal of exposures has resulted in elimination or mitigation of the potential of many dropped objects on our rigs. Maintaining a proactive approach in support of our employees and rigs allows us to continue to make improvements in this area. This includes involvement by employees throughout the organization - supply chain, technology, operations and HSE teams - as we continue to look for more effective and innovative ways to address those exposures. Crack! Pop! Thud! Smash! Boom! ASKING "WHAT IF?" A SIMPLE CONCEPT WITH A BIG IMPACT u Complete all dropped object inspections in the cadence they are required u Correcting any deficiencies noted in timely manner u Perform a final walk around or visual inspection prior to raising the mast u Utilize the Tools at Heights Checklist u Verify all equipment that was taken overhead for work has been brought back down u Honor all barricades and buffer zones per procedure for working overhead, rough drilling, and day to day tasks u Ensure secondary retention is in place during all equipment installations, if required, and change out if needed u Think outside the box: stop the job and find ways to eliminate any potential dropped objects from the work location - you are the ones completing tasks daily. 05.24_V1.0 Interested in our 2024 Actively C.A.R.E. Goals? Scan to see where we are putting our safety focus. WWW.HELMERICHPAYNE.COM

You plan your well to be safe, but when deviations from plan inevitably occur an updated analysis must be performed to confirm that the new execution plan is still safe. Traditional risk management processes can sometimes work against your desired outcome by being inefficient and creating frustration. They are also dependent on human variables that require more support and can have a high level of variance or bias. H&P Collision Avoidance provides frustration-free anti-collision analysis that does not compromise time to target due to decision delay and removes the de-manning barrier required by traditional collision avoidance systems.

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.

Fluctuations in rotary speed and damaging lateral vibrations can result in stick slip, whirl, and overall downhole tool failure. H&P's FlexTorque® technology actively responds to torque fluctuations by adjusting top drive RPM to help mitigate stick slip and other BHA failures. Avoiding trips, stuck pipe, fishing jobs, and damaged BHAs all equate to reduced emissions, time to target, and costs.

For over 100 years, Helmerich & Payne has been a leader in rig performance and more recently, in rig technology and innovation. H&P is the largest onshore driller in the US and has approximately 25% of the total horizontal and 34% of the superspec market share in US land drilling. Having operated in international markets for the last 64 years, and with 800+ employees working outside of the US, we are positioned to deliver better drilling outcomes across the globe.

Delivering better outcomes with rig floor automation

Fatigue prediction is usually based on the cumulative fatigue damage model from Hansford and Lubinski as defined in API RP7G. This model, based on S-N curves, a failure criterion and a damage accumulation rule, initially requires a calculation of the drillpipe stress caused by bending when rotated in a dog leg. This bending stress calculation, key point of the cumulative fatigue damage model, is usually made by assuming that the curvature of the drill pipe is the same as the dog leg. However, this paper shows that this strong hypothesis may lead to major under-estimation of the cumulative fatigue damage. Moreover, the stress distribution within a drill pipe may be completely different depending mainly on the position of the drill pipes along the drillstring and the wellbore architecture and tortuosity. Reach out to us to learn in detail: https://www.helmerichpayne.com/resources/technical-publications/drill-pipe-stress-and-cumulative-fatigue-analysis-in-complex-wells-drilling-new-approach-in-fatigue-optimization or you can contact us here: https://www.helmerichpayne.com/contact.

Challenge A major operator in the Midland Basin had been using the H&P Bit Guidance System with AutoSlide® Technology as their solution to successfully build and scale their remote directional drilling. Although AutoSlide technology was consistently producing better than average curve times, there seemed to be a curve time "ceiling" around 11 hours. H&P believed that curve times below 8 hours were possible in this basin, and set out to raise the bar and help ensure this operator was achieving optimal performance. Solution H&P aims to treat every customer relationship as a true partnership, which is why our Directional Team approached the operator with a bold plan to pause AutoSlide technology for the curve section of the hole where the "ceiling" seemed to exist. Their idea was to drill some of the curves manually to gain new perspective on what could be hindering optimal performance so that they could help the operator achieve their desired outcome.

H&P's Advanced Well Engineering service combines the vast experience of their engineering team and DrillScan® digital solutions, an industry-leading technology, to optimize the delivery of high-performance wells for operators. Our comprehensive solutions are tailored to help you achieve your desired outcome by addressing critical areas such as drilling performance, operation efficiency, and well design. We offer reduced cycle times, lighter well architectures, and measures to minimize exposure to safety hazards associated with drilling operations.

Today, drillers are responsible for changing and executing roadmap parameters at the right time or they face a number of risks - one being damage to BHA tools. Digital Roadmap takes the drilling roadmap concept and automates the process through a digital platform. H&P can now take specific drilling roadmaps ahead of each well and enter it into Digital Roadmap, which will then execute that roadmap in an automated fashion. This means that when a roadmap calls for a specific reduction in RPM and weight on bit (WOB), the rig will automatically reduce drilling parameters through critical formations and transition zones.

Staging drilling setpoints after tagging bottom is often inconsistent and can cause drilling dysfunction. H&P transformed this common multi-step task into an automated and configurable process with FlexB2D® technology. Now, with FlexB2D 2.0 operators can realize even more efficiencies than were available before. FlexB2D 2.0 technology performs automated zeroing of the weight-on-bit (WOB) and differential pressure setpoint and helps ensure proper contact with the formation. Automated, configurable, consistent bit engagement ultimately reduces BHA failures and decreases time to target.

Everyone experiences stress and anxiety, whether it stems from workload, work environment, family challenges, or financial struggles. Sometimes, it results from a traumatic incident or the loss of a loved one. Whatever the cause, we all encounter it at some point. Understanding how to address mental health challenges and knowing the available resources can make a world of difference.

The drilling and completion of oil and gas wells is a collaborative business, involving employees from many contractors working together. Well construction generates many documents that are shared cross-functionally between these different groups. A regulator may receive an as-drilled plat from a well planner, using surveys from an MWD operator, based on a pipe tally from a rig contractor. In this scenario, the person legally specifying the well location has likely never physically seen the wellhead or the equipment used to define the location. The regulatory database might later be used by a different operator for identifying offset wells on a nearby drilling program, further confounding matters. While document sharing is critical for successful well construction, there is often little opportunity for verification before use or transmission to another party. A review of documents related to well construction was performed. This included plats, well plans, bottom hole assembly reports, directional surveys, and other drilling records. The examination was performed on which data was contained in these documents, how it might be verified by a third party using it, and the potential for errors to arise when the data is received or transmitted. Of particular concern were documents such as well locations and directional surveys which are not only difficult to verify but are also likely to be further shared with additional parties.

H&P is known for our best-in-class technology and industry-leading rig designs, developed and maintained by the specialized, purpose-driven expertise of our workforce in the field and beyond. Recruiting, hiring, onboarding and initial industry-required training completed offline to begin rig operations Reduces area silos and provides a holistic view of workforce and staffing needs Removes unnecessary burden on Rig Manager recruitment responsibility Detailed analysis of current and future workforce needs Maintain a "bench" of trained and skilled employees is ready for deployment at a moment's notice Best-in-class reduction in workforce processes during downturns allows retention of higher skilled labor and provides employees affected by Reduction In Fleets an opportunity to get back to work as quickly as possible.

The drilling industry has undergone significant changes in recent years, leading to increased efficiency, lower costs, and reduced emissions per production unit. As unconventional well construction complexity continues to increase, the next wave of innovation lies in process automation, offering improved consistency and the opportunity to enhance drilling engineering designs. Effectively automating drilling a stand while minimizing human variability requires a scalable control system, providing adaptability, seamless implementation, and improved operational outcomes. The system requires highand low-level process control components to effectively control rig machinery within the bounds of the machine limit controls. By using automation sequences while engaging and disengaging the drill bit, operational states such as breakover, optimal weight on bit (WOB), steady state hookload, and zeroing become easier to distinguish. Through consistent implementation of process automation in drilling operations, the impact on operational outcomes became evident. Analysis of bit disengagement in a series of automatically drilled stands in the lateral revealed a consistent breakover range of 18 to 22 ft. This is particularly noteworthy as breakover is typically more challenging to identify and prone to variability in manual operations. Zeroing WOB in the lateral at a predetermined drilling interval is common practice to calibrate the drilling system, and procedures provided by the operator are often conservative due to human variability resulting in slower process execution. While drilling automated stands in a lateral, it was determined the lowering sequence of the process could be reduced by half to effectively zero the WOB and differential pressure, reducing invisible lost time. Not all invisible lost time and variability is human related; variability due to equipment design was reduced.

This study demonstrates that the procedure reduces the horizontal wellbore position uncertainty by 46% for the study area and more generally from 15 to 50 percent when compared to standard MWD (Measurement While Drilling) survey technology. Furthermore, this method was compared to a typical IFR model created from airborne measurements. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/achieving-iscwsa-mwd-ifr1-tool-codes-without-airborne-magnetic-surveys or directly contact us at: https://www.helmerichpayne.com/contact.

Drillstring vibrations habitually cause downhole BHA failures. While the drillstring will always be subject to these vibrations, H&P has developed a physics-based module that selects the optimal BHA design to enhance overall drilling performance. • Quantifies the severity of vibrations along the string • Benchmarks multiple BHA proposals with a few clicks • Recommends peak drilling parameters for any type of BHA • Helps ensure adequate placement of sensitive equipment • Simple & accessible for all levels of drilling engineers

Efficient drilling through heterogenous geology requires careful matching of drilling parameters to the rock being drilled. Failure to do so can lead to increased bit damage or poor drilling performance. The "driller's roadmap" is a list of such parameters to be changed at various depths where formation tops are expected to be crossed. To learn more, visit us here: https://www.helmerichpayne.com/resources/technical-publications/successful-execution-of-a-dynamic-drillers-roadmap-using-an-automated-formation-top-detection-algorithm or reach out to us directly: 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.