The continuous evolution of the energy industry, driven by decarbonization goals and digital transformation imperatives, has led to significant advancements in drilling operations. This article explores the integration of advanced digital tools, real-time monitoring systems, predictive analytics, and automated drilling rigs as key enablers of operational excellence in upstream activities. A comprehensive overview is provided on how closed-loop digital workflows, adaptive control systems, and automation technologies have improved drilling efficiency, reduced non-productive time (NPT), enhanced safety, and supported environmental sustainability efforts. The paper presents an in-depth case study conducted in a Romanian gas field, where targeted drilling optimization initiatives were implemented across multiple well sections. In addition to digital enhancements, the use of Non-Aqueous Drilling Fluids (NADF) was a decisive factor in overcoming geological challenges associated with reactive shales and unstable formations. Compared to conventional Water-Based Muds (WBM), NADF systems delivered superior wellbore stability, reduced filtrate invasion, higher rate of penetration (ROP), and improved compatibility with directional drilling. Through real-time parameter adjustments, connection efficiency improvements, surveying strategy optimization, and dynamic management of critical-path activities, cumulative time savings exceeding five rig days per well were achieved. The study also highlights the benefits of predictive maintenance, adaptive drilling practices, and digital twin simulations as future avenues for further optimization. The findings demonstrate that a strategic approach combining advanced technology, high-performance drilling fluids, real-time operational intelligence, and continuous improvement frameworks can substantially enhance drilling performance, reduce costs, and support sustainable field development. The article concludes by identifying future focus areas such as adaptive drilling systems, machine learning-driven predictive analytics, expanded use of digital twins, and organizational standardization, offering a roadmap for achieving resilient and competitive drilling operations in the context of the global energy transition.

Direct comparisons of structurally distinct carbon-based additives in water-based drilling fluids under identical conditions remain limited. This study evaluated grapevine-wood-derived carbon (GWC), graphitic carbon nitride (GCN), and commercial activated carbon (CAC), each incorporated at 20 g per formulation. Their structural, morphological, and textural properties were characterized, and their effects on rheology, API filtration, and 72 h linear shale swelling were assessed. GWC exhibited the highest DFT-derived specific surface area (939.17 m² g⁻¹) and, among the tested formulations, provided the best filtration performance, reducing fluid loss from 8.0 to 5.6 mL and mud-cake thickness from 1.5 to 0.5 mm. Although GCN possessed the lowest specific surface area (32.50 m² g⁻¹) and produced comparatively unfavorable filtration behavior, it produced the greatest reduction in shale swelling, decreasing final swelling from 12.2% to 7.3 ± 0.2%, corresponding to a 39.9% reduction relative to the carbon-additive-free reference formulation. GWC and CAC both limited swelling to 9.2%, while CAC produced intermediate filtration performance. These contrasting responses demonstrate that specific surface area and porosity alone do not determine additive performance. Among the tested formulations, GWC provided the best filtration control, whereas GCN produced the greatest reduction in shale swelling.

As the energy sector confronts the dual imperatives of decarbonization and digitalization, OMV Petrom has initiated a comprehensive transformation of its upstream operations through the DigitUP program. This paper explores the company’s strategic integration of advanced digital technologies into its drilling workflows, emphasizing the deployment of automated drilling systems, real-time monitoring platforms and data-driven optimization tools. Central to this transformation are the cloud-based drilling reporting system, coherent well planning solution, real-time drilling data monitoring platform, drilling performance management system and the AR 150 automatic rig, all of which contribute to a closed-loop digital workflow encompassing planning, execution and post-well analysis. The study presents operational and performance data illustrating significant improvements in drilling efficiency, including increased rate of penetration (ROP), reduced well delivery time and minimized non-productive time (NPT). Key performance indicators (KPIs) are utilized to track operational behavior and guide continuous improvement, while predictive analytics and machine learning algorithms enable dynamic parameter adjustment and failure prevention. Additionally, using electrical rigs and automation of tasks support OMV Petrom’s sustainability and safety objectives. The findings demonstrate that OMV Petrom has established a scalable, digitally integrated model for high-performance drilling. This approach not only enhances organizational agility and technical excellence but also aligns with broader environmental and economic goals. The paper concludes that the DigitUP initiative positions OMV Petrom as a leading example of how legacy oil and gas operators can successfully transition toward a future-ready, data-driven operational paradigm.