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Performance contracts are increasingly common in the drilling industry, especially in recent years. This incentivized contract structure, established as a partnership between operator and contractor, improves both well performance and operational execution while incorporating the rig contractor as an additional stakeholder in the operational performance of the well. Many performance contract styles exist, with one common goal: if targets are met, all parties involved benefit. An increasingly common performance contract type is a tier-structure KPI (Key Performance Indicator) format. In this format, metrics in the form of KPIs are determined, and goal ranges are set in a tiered system. Prior research and data collection, requiring effort from multiple departments, is needed to determine achievable and stretch metrics. After the goals are agreed upon, field personnel, experienced rig leadership, and comprehensive technology support are determined, forming a foundation for success.

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.

Performance contracts are increasingly common in the drilling industry, especially in recent years. This incentivized contract structure, established as a partnership between operator and contractor, improves both well performance and operational execution while incorporating the rig contractor as an additional stakeholder in the operational performance of the well. Many performance contract styles exist, with one common goal: if targets are met, all parties involved benefit.

Drilling practices alone are not enough to accurately deliver a high quality wellbore, as success is equally dependent on the accuracy of the wellbore survey. H&P's Survey Management increases the accuracy and consistency of how we measure boreholes, enabling the delivery of any outcome that relies on knowledge of the wellbore position or shape. These outcomes include landing a curve, properly spacing laterals, safely performing collision avoidance operations, and updating well plans and geological models to accurately reflect data that was measured while drilling.

In the current drilling climate, efficiency is king: do more with less. This motivation drives disruptive technological innovations in automation of the drilling process. Drilling automation can contribute to this efficiency specifically by automating the sliding process. The paper discusses a case history involving one operator's deployment and results of an automated sliding system. Learn more about us: https://www.helmerichpayne.com/resources/technical-publications/automated-sliding-efficiencies-achieved-in-the-next-stage-of-drilling-automation or you can reach out to us directly here: https://www.helmerichpayne.com/contact.

Our FlexRig® fleet offers configurations to deliver more power, more finesse, and greater mobility to match the demands of your operations. › The industry leader in performance and safety › Multiple configurations to match the unique demands of your drilling operation › Integrated advanced technologies paired with fully autonomous solutions

We hear the term quite often within the drilling industry. But what does it really mean? Is it even possible to achieve in an industry that operates daily with elevated risk factors? We know it to be true: equipment will fail, and as long as people are involved in the work, failure from human factors is inevitable at some point. However, it is possible for failures to occur in the workplace while maintaining worker safety. In fact, this is what we all should be striving to achieve. That's why the concept of a "SIF-mitigated" category was introduced - framing these mitigated incidents in a positive light, representing the ability to fail safely.

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.

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.

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.

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.

Leveraging a unique combination of computing algorithms and capable, autonomous controls, our geosteering solutions recognize and avoid risks, both before and while drilling. This accuracy results in a reduction of average drill time, while securing greater production potential of completed wells. Put FlexFusion and the power of automation to work for you-and your bottom line. Contact Us - https://www.helmerichpayne.com/contact/contact-sales Know More About H&P Drilling Automation - https://www.helmerichpayne.com/drilling-automation.

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.

Tighter well spacing, multi-well pad designs, and longer laterals create drilling conditions with higher collision risk and the need for greater positional accuracy. Using high-accuracy In-Field Referencing (IFR) models will improve anti-collision separation factors (SF) by as much as 60% as compared to main field magnetic models used in standard MWD surveying. This not only reduces collision risk, but also enables more accurate well placement. IFR does NOT require additional downhole tools, on-site personnel, or rig time. IN-FIELD REFERENCING (IFR) IFR is an industry-recognized, low-cost method for reducing wellbore positional uncertainty associated with MWD surveying. Applying IFR can significantly increase the SFs for wells drilled in congested fields. While H&P survey corrections do not require re-entry/re-surveying old wells, that option is available to further reduce uncertainty of previously drilled wells in congested fields. Higher SFs will require fewer dispensations and reduce risk of well-to-well collision and lease line infractions. Reducing positional uncertainty also enables future in-fill drilling campaigns. Main field geomagnetic models used in standard MWD do not capture local crustal anomalies of the geomagnetic field. IFR is the industry-leading method of accurately predicting the magnetic field magnitude and direction for a geographic location and time. IFR relies on independently acquired measurements of the local magnetic field to accurately map regional variations caused by magnetic minerals in the Earth's lower crust.

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.

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, 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. 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. This integrated system is coupled with oversight from expert directional drillers in a remote directional drilling command center.

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.

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.

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.

By using the continuous surveys taken by an MWD tool, to account for the actual tortuosity of the well, the potential fatigue becomes even more significant. Read out the full tech paper here: https://www.helmerichpayne.com/resources/technical-publications/fatigue-tracking-for-mud-motors-and-mwds-in-unconventional-wells or you can also download the pdf from here: https://www.helmerichpayne.com/media/technical-publications/Fatigue-Tracking-for-Mud-Motors-and-MWDs-in-Unconventional-Wells.pdf. Contact us to know more: https://www.helmerichpayne.com/contact.