How Technology can Boost Drilling Performance

Attention Directional Drillers - There's a new Tool for your Toolbox Directional drillers face relentless challenges—excessive tool wear, torque, drag, poor hole cleaning, and unreliable data. The culprit? Contaminants in the drilling fluid. The solution? X-ray Fluorescence (XRF) and Particle Size Analysis (PSA)—two cutting-edge diagnostic tools that provide real-time, actionable insights into fluid composition and performance. XRF and PSA quantify the critical parameters that impact drilling success: Quartz content, LGS/HGS, Ultrafine, Colloidal Particles, Lubricity and Iron Filings wear indicators. By leveraging these advanced measurement technologies, drillers can: ✅ Extend tool life by proactively detecting abrasive contaminants. ✅ Reduce ILT & inefficiencies by optimizing solids control. ✅ Enhance lubricity to reduce torque, drag, and elastomer wear. ✅ Improve MWD/LWD signal integrity by mitigating magnetic interference from iron filings and other magnetic particles. ✅ Ensure precise wellbore trajectory by maintaining fluid consistency. Data-driven drilling is the future. This Tech Talk explores how XRF and PSA empower drillers to take control of the mud system contaminants, reduce non-productive time (NPT), reduce Invisible Lost Time (ILT) and maximize operational efficiency. Contact NPTLABS™ - Offshore | Onshore Onsite Solids Control Lab with XRF | XRD and PSA Capabilities for more details on how digital solutions can help. Measuring Mud Matters

Imagine a future where drilling rigs can predict and prevent failures before they happen—this is the power of digital twin technology. The oil and gas industry is undergoing a digital transformation, and one of the most promising advancements is the integration of digital twin technology into drilling operations. Recent studies introduce a comprehensive digital twin framework for gear rack drilling rigs, focusing on the lifting system. This approach combines mechanism modeling, real-time performance response, and data visualization to enhance operational efficiency and predictive maintenance. Key highlights: Real-Time Data Integration. Utilizing sensors for continuous monitoring, enabling immediate response to performance deviations. Predictive Analytics. Employing machine learning to forecast potential failures and optimize maintenance schedules. Enhanced Visualization. Implementing Unity3D for immersive visualization of system behaviors and performance metrics. Modular Framework. Designing a flexible system that can be adapted to various drilling scenarios, promoting scalability and adaptability. This innovative framework not only improves the reliability and efficiency of drilling operations but also paves the way for the development of intelligent and unmanned drilling rigs.

Advancements in deepwater drilling are here! Baker Hughes' latest article in Drilling Contractor delves into how real-time fluid measurement is revolutionizing the industry by delivering greater certainty, safety, and efficiency to deepwater well construction.   Key highlights: ➡️ Continuous Real-Time Monitoring: AFM system provide continuous, real-time measurements of key fluid properties like density and rheology, enhancing drilling safety and efficiency. ➡️ Enhanced Safety: The AFM system reduces risks associated with manual sampling, such as exposure to hazardous materials and human error. ➡️ Operational Efficiency: Early detection of issues like barite sag allows for timely corrective actions, minimizing downtime and maintaining optimal drilling performance. ➡️ Technological Innovation: The AFM system integrates seamlessly with existing drilling automation services, optimizing key drilling activities and ensuring proper pressure control.   Discover how Baker Hughes is leading the way in deepwater drilling technology and helping operators drill wells faster, safer, and smarter.   Read the full article to learn more about these groundbreaking advancements and their impact on the industry - https://lnkd.in/e3h6cHkF   #WeAreBakerHughes

🚀 Let's talk about Corva, this week’s highlight in our Baker Hughes Digital Well Construction 101 series. 🚀 When drilling a well, you need to operate at peak efficiency. Every well, every time. And you want to drill each well better than the last. Efficiency, Consistency and Results 👉 That’s what you get when Baker Hughes, the leading energy technology company meets Corva’s App Store for Energy. With standard applications designed to address a range of common drilling challenges, we turn raw data into actionable insights, driving efficiencies across the operation. These insights allow us to identify, measure and mitigate well construction issues, reducing NPT and ILT to ensure consistent, predictable drilling. With the data already captured and contextualized on an open, collaborative platform, we can build bespoke applications to address unique drilling challenges and drive continuous improvement across all drilling activities. Corva’s Dev Center provides the app platform to build exactly what you want, fast. At Baker Hughes, we are using the Corva platform combined with our analytics solutions built in Corva’s Dev Center to bring insights and savings to our customers all over the world. Corva’s platform supports wellsite operations on hundreds of rigs and from remote operations centers worldwide. Recently, we released five Baker Hughes Drilling Optimization apps on the Corva App Store. With TotalEnergies in Argentina, the teams used our i-Trak Advisory software to drive performance and Corva applications for real-time data analytics, resulting in an impressive +84% increase in on-bottom ROP and a -36% reduction in W2W times in the 12-1/4” section. Interested in learning more? Click here 👉 https://lnkd.in/d5p94tVR. #BakerHughes #WeAreBakerHughes #Digital #Technology #DigitalTransformation #OilAndGas #DigitalWellConstruction #Energy #Corva

AI's Transition from Pilot to Production in Oil & Gas The oil and gas industry stands at a critical inflection point. While AI has proven its value in reducing unplanned downtime, optimizing drilling parameters, and extending equipment life, most operators remain trapped in "pilot purgatory", running impressive demonstrations that never scale beyond single wells or facilities. The difference between AI pioneers and laggards is becoming a measurable competitive gap: 15-25% drilling efficiency improvements, 40-60% longer ESP run-life, and millions in avoided downtime. The challenge isn't technological, it's operational integration. Successful AI implementations require more than sophisticated algorithms; they demand seamless data unification across SCADA systems, explainable outputs for regulatory compliance, and embedded decision support where engineers actually work. Companies that solve the integration challenge first will dominate tomorrow's unconventional plays and offshore developments. This analysis examines how leading operators are moving AI from science project to profit center, the specific use cases driving measurable barrel and BTU gains, and the platform capabilities required to scale AI across drilling, production, and midstream operations. For an industry where a 5% EUR improvement can mean millions in additional revenue per well, AI isn't just technology, it's competitive survival. The following deep dive explores both the opportunities and implementation strategies that separate AI leaders from followers in upstream and midstream operations.

Improve Your Wells Value Proposition – this requires immediate capex reduction followed by wells life cycle value improvement Energy transition outlooks are pivoting to the realization that oil and gas will remain a key constituent for years to come. Projections (Rystad) show that an additional 56 million barrels a day will be needed by 2030 simply to offset reservoir depletion. However, projected increases in stockpiles of oil can cause downward pressure on pricing. Costs for hydrocarbon development are important as investors demand capital discipline, the need for oil and gas delivery to compete with declining green energy costs and the access to reservoirs becomes more challenging. Wells capital is particularly important because it constitutes a significant portion (often 50%) of a field development cost. Field development economics require both mitigation of capital and operating well costs and a deterministic value (budget / AFE). Well costs are impacted from the concept stage through construction, operation and abandonment which are interdependent with subsurface modelling and facilities design. Project NPV is impacted by both the capital cost (Capex) and operating cost (Opex) as well as the revenue stream (production). Realization of maximum NPV can only be achieved through a full well life cycle appreciation. Significant reduction in well construction (drilling and completion) duration not only drives a reduction in capex, but it also accelerates production realizing improved NPV. Oil and gas clients require the near-term positive impacts on their Capex with a long-term improvement in value (net income). Client diagnostics performed with data analysis and face-to-face interviews leads to an articulation of current state for client debate and confirmation; insight sharing and debate leads to a collectively (operator multiple competencies and suppliers) developed aggressive future state opportunity. Lean Drilling™ workshop facilitates clients to generate initiatives that rapidly cross this gap, deliverables and timelines drive near term step change in well construction (drilling and completion – capex). Results achieved include up to 50% drilling / completion time reduction, 30% cost reduction, 50% production increase ranking best in class global drilling performance on Rushmore Review from a step change implementation. Happy to facilitate. Creating real collaboration across disciplines is the true lever to generate improved value through opportunistic well concepts, lowered reservoir modeling uncertainty, increased productivity and reduced abandonment costs. Enhancing this collaboration across any organization enables harvesting the maximum value from field development life cycle. Keys to this door include developing a highly effective life cycle organizational architecture, creating joint value goals, mitigating life cycle risks, effectively implementing digitalization. Climb on board – DM me! #spe #iadc #oilandgas #drilling 

Halliburton designed an 8-1/2-in. Hedron® drill bit, equipped with Razor 4D-shaped cutters, Cerebro Force™ in-bit sensing, and Oculus™ automated dull grading technology to help improve drilling operations for a deepwater exploration well.   The optimized Hedron bit configuration increased footage by 45% and rate of penetration by 68% over the previous record. Read the full case study to learn more.

Facing low rates of penetration (ROP) in an unconventional, vertical deep gas application, an operator sought to enhance performance and rerunnability.   Through the Design at the Customer Interface (DatCI™) process, Halliburton collaborated with the customer to create a drill bit that optimized efficiency and performance.   The result? The new Hedron® bit design drilled 2,336 feet using a motor BHA, achieving an impressive ROP of 267 feet per hour—the highest in the field at the time. This demonstrates a substantial 15% improvement on the previous field record. Read the full case study >> https://lnkd.in/gRuDX5QU