Opening new frontiers in formation evaluation: Transforming subsurface insight with intelligent imaging-while-drilling

FRANCOIS VAN VLIET, SLB 

MEETING THE NEXT GENERATION OF FORMATION EVALUATION CHALLENGES 

Advancements in formation evaluation have long propelled the frontiers of well construction and field development. Today’s quest for enhanced subsurface insight entails more than acquiring basic log curves. The challenge lies in interpreting complex geologies, minimizing risk, and maximizing recovery—all without slowing the pace of drilling. This need is especially pressing where operational demands drive high rates of penetration (ROP) and real-time, actionable data is essential to well placement and reservoir management decisions. 

Traditional logging-while-drilling (LWD) imaging tools struggle to meet these expectations, particularly at high ROP. Operators often encounter image gaps, degraded resolution, and data loss, due to the limitations of the hardware and compression algorithms, compounded by harsh downhole dynamics, such as stick-slip, shock and vibration. These shortcomings historically forced a tradeoff between drilling efficiency and geological understanding. 

WHAT “INTELLIGENT IMAGING-WHILE-DRILLING” MEANS FOR BUSINESS 

Intelligent imaging-while-drilling turns borehole images from a dataset into a decision system that keeps pace with modern drilling. The goal is simple: deliver decision-quality subsurface clarity while the bit is turning—so teams can make high-impact calls (landing, steering, pressure management, and completion placement) without waiting for post-run downloads or sacrificing drilling performance:. 

• Operational continuity. Continuous images at high ROP reduce “blind” intervals that can drive course corrections, reaming or unnecessary sidetracks. 
• Faster decisions, fewer delays. Critical geological features arrive at surface in real time, shortening the decision cycle between rig and office and reducing the need to slow down for data quality. 
• Lower uncertainty, better economics. Higher-confidence well placement and completion zoning reduce the probability of watered-out intervals, suboptimal stage placement and missed pay—protecting both production outcomes and capital efficiency. 

Recent developments in intelligent imaging-while-drilling are redefining what’s possible. By combining robust imaging hardware, advanced real-time data compression, and seamless multisensor data integration, SLB’s latest generation of while-drilling imaging technology, MicroScope Ultra™ intelligent imaging-while-drilling service, is designed to address limitations of earlier systems. A recent deployment in the Middle East shows how these advances are setting new benchmarks for formation evaluation. 

HIGH-RESOLUTION IMAGING AT ELEVATED RATES OF PENETRATION 

A key breakthrough is the delivery of continuous, high-definition borehole imagery at rates of penetration up to 280 ft/hr (85 m/hr)—well beyond the limits imposed by previous technologies. This achievement rests on a robust sensor platform designed to maintain image quality despite drilling-induced shock and vibration. Real-time data streams preserve geological features continuously, even as drilling parameters fluctuate, thereby supporting uninterrupted drilling operations without the loss of critical subsurface information. 

The success of this approach is rooted in the integration of feature-based compression for borehole images (FCBI). Rather than compressing every data packet, FCBI intelligently differentiates between essential geological content and less critical image background, enabling real-time, lossless transmission to the surface. This approach helps maintain image fidelity, reducing decision reliance on post-drilling memory downloads and reducing uncertainty. 

Reducing reliance on post-run downloads translates into faster convergence on key decisions and fewer schedule disruptions. Continuous, trustworthy imagery helps avoid the costly “pause and verify” pattern that can emerge when teams question data quality—protecting drilling cycle time while lowering exposure to nonproductive time from additional evaluation runs or rework. It also improves cross-team alignment: when geology, drilling, and reservoir stakeholders are looking at the same real-time picture, approvals and course corrections happen faster, and completion zone selection can be made with greater confidence. The net effect is a tighter connection between real-time execution and long-term well value. 

Continuous, high-quality imaging not only supports standard interpretations but also promotes advanced applications, such as near-wellbore structural analysis, detection of thin beds and fractures, mud-cake characterization and improved geomechanical modeling. With each foot drilled, operational teams receive a complete, high-resolution snapshot of the borehole environment—enabling more confident and responsive decision-making. 

MULTI-TECHNOLOGY INTEGRATION FOR ENHANCED SUBSURFACE INSIGHT 

Another critical advancement is the native integration of multiple subsurface measurement streams—including nuclear magnetic resonance (NMR) and distributed acoustic sensing (DAS)—alongside borehole imaging. This multi-technology platform provides a richer geological context by combining quantitative porosity, permeability and fluid mobility data with high-definition visual imaging and acoustic insights. 

This comprehensive dataset unlocks new levels of formation evaluation. In the case study, the operator leveraged the synergy between advanced imaging and NMR/DAS to accomplish: 

• High-confidence facies typing, using integrated imaging and NMR porosity profiles as a foundation for reservoir modeling. 
• Water-corridor detection through combined acoustic and image-log interpretation, which reduced the risk of unexpected water production. 
• Optimized completion designs driven by the confluence of visual and petrophysical data, enabling precise selection of completion zones and minimization of unwanted fluid breakthrough. 

This multi-stream data approach transforms formation evaluation from a patchwork of individual measurements into a holistic reservoir characterization platform, aligning real-time operational decisions with long-term asset value. 

MIDDLE EAST CASE STUDY: PUSHING THE BOUNDARIES 

An onshore carbonate reservoir in the Middle East served as a test case for these advances. The goal: to achieve real-time, high-resolution imaging and formation evaluation—even at ROPs up to 280 ft/hr—in a geologically complex, operationally demanding environment. 

Objectives and historical limitations. 

Fig. 1. Feature-based compression of borehole images (FCBI), Enables high-fidelity reconstructions of critical geology features at ultra-low bandwidths.

Previous LWD imaging deployments in the basin were hampered by image gaps, poor resolution, high ROP and borehole dynamics. This resulted in obscured small-scale formation features—which required a choice between compromising operational efficiency through slower ROPs or additional runs, or geological interpretation leading to an incomplete reservoir model.

These historical limitations create a compounding cost. Image gaps and degraded resolution don’t only reduce interpretation quality—they slow the decision cycle and introduce execution risk at the very moments when teams need confidence. In practice, uncertainty forces conservative behavior: slowing ROP to “protect” data quality, adding evaluation runs, or widening geosteering margins to avoid boundary risk. Each response can increase rig days and amplify nonproductive time exposure, while also raising the likelihood of suboptimal well placement. 

In carbonate settings, where thin flow units, fractures and water corridors can dominate performance, missing small-scale features can carry forward into completion planning—impacting stage selection, drawdown strategy and water management over the life of the well. The operator’s challenge was, therefore, not purely technical; it was about preserving drilling efficiency while protecting reservoir contact and long-term well value. 

The operator required a new approach for: 

• Maintaining continuous, high-resolution imaging at any ROP, especially in challenging conditions 
• Reducing sensitivity to dynamic drilling events (stick-slip, shock, vibration) 
• Providing real-time surface access to all critical image data without gaps 
• Integrating additional advanced LWD measurements—such as NMR and DAS—seamlessly alongside imaging. 

Solution deployment.  

During a 3,200-ft (975-m) drilled section, the imaging-while-drilling tool delivered on all these requirements, Fig. 1. Robust downhole hardware maintained resolution and coverage throughout high ROP. Feature-based compression (FCBI), real-time transmission ensured that all geological features were captured. Integrated NMR and DAS measurements provided context and advanced formation characterization. 

OUTCOMES AND NOTABLE ACHIEVEMENTS 

Several desired results were achieved in this test case, as follows: 

• High-fidelity imaging. Continuous, high-definition borehole imagery at ROPs as high as 280 ft/hr No observable loss in data or resolution under dynamic drilling conditions. 
• Real-time insights. FCBI enabled immediate, complete image transmission to surface, reducing traditional wait times associated with memory download. 
• Comprehensive subsurface model. Seamless integration of imaging, NMR and DAS allowed detailed facies typing, detection of water corridors and real-time operational adjustments. 
• Informed operations. Twenty-seven formation pressure-while drilling (FPWD) pretests were performed in sequence, producing a continuous pressure profile and supporting both safe drilling and optimal completion design. 

This deployment established new performance baselines by translating better data into better outcomes: lower geological uncertainty, stronger well placement confidence, reduced operational disruption and faster, more coordinated decisions across the well delivery team—enabled by actionable real-time data rather than post-run reconstruction.  

BENCHMARKING PERFORMANCE IN FORMATION EVALUATION 

The successful use of MicroScope Ultra™ in the Middle East highlights several industry-first achievements and market differentiators: 

1. Imaging at high ROP without compromising data quality.  

Where operators once slowed ROP to preserve image quality, now, clarity and completeness of subsurface imagery at any drilling speed are possible. Real-time, high-resolution visualization allows teams to stay in the target zone and to make confident decisions, even amid challenging geology and operational demand. 

2. Data integrity and timeliness.  

Feature-based compression supports the integrity of all geological features in real-time surface data. The technology enables teams to trust every interpretation and phase of well construction, from mud logging to completion design. 

3. Workflow integration for the digital oil field.  

Integration of borehole images, NMR and DAS fosters a more collaborative workflow across subsurface teams. The data are immediately actionable, whether for geosteering, petrophysical modeling or geomechanics, reducing handoff delays and enabling a truly digital decision cycle. 

4. Platform for continuous innovation.  

The technology’s modular and software-driven design means future measurement enhancements and analytical workflows can be quickly adopted. As drilling challenges and field requirements change, the platform is ready to support new energy applications and automated or AI-driven analytics, ensuring continuous improvement and long-term operational value. 

OPERATIONAL BENEFITS FOR RESERVOIR NAVIGATION AND OPTIMIZATION 

Fig. 2. High-resolution borehole imaging in real time at ROPs of 280ft/hr (85m/hr), for actionable geology and petrophysics insights to maximize operational and economic efficiency (SPE-226735-MS).

Access to high-resolution imaging in real time, Fig. 2—combined with quantitative NMR and DAS data—enables operational teams to: 

• Steer more accurately in heterogeneous reservoirs 
• Rapidly classify facies and identify thin beds, fractures, or subtle sequence boundaries 
• Advance pressure management with in-situ formation tests at the informed “sweet spots” 
• Fine-tune completions to maximize drawdown, minimize water cut and optimize production sustainability. 

ACCELERATING THE ENERGY TRANSITION AND DIGITAL TRANSFORMATION 

While the technology’s initial impact is in traditional oil and gas applications, its reliable high-definition imaging and multi-technology integration are also applicable to emerging domains, such as geothermal and CCUS. The solution’s digital architecture supports integration into advanced analytics, automation and cloud workflows, empowering efficient, human-in-the-loop or increasingly autonomous field operations. 

COLLABORATION—LOCAL IMPACT, GLOBAL REACH 

Critical to the success of the Middle East project was the close collaboration between the operator’s teams and local technical experts. By directly supporting planning, calibration, interpretation and operational troubleshooting, this approach helps ensure that technology aligns with the unique requirements and challenges of each field. 

LOOKING FORWARD: THE FUTURE OF FORMATION EVALUATION 

As drilling campaigns become more complex, and subsurface environments more demanding, adoption of high-performance, intelligent imaging-while-drilling technology will mark a new era in formation evaluation, Fig. 3. For operators pursuing both traditional and low-carbon energy objectives, the formula is clear: advanced, real-time data platforms that adapt to the needs of the well—rather than imposing new constraints. 

Fig. 3. MicroScope Ultra™ intelligent imaging-while-drilling service.

Operators can anticipate an acceleration of: 

• Geosteering efficiency. Confidence in staying within optimal reservoir targets, even at fast drilling rates. 
• Data-driven completions. Placement decisions, informed by fully integrated petrophysical and mechanical context. 
• Subsurface assurance for CCUS and geothermal projects. Reliable imagery and multi-sensor measurements, supporting risk reduction and regulatory requirements. 
• Digital transformation. Open architecture and digital workflows accelerating insight, collaboration and value. 

These developments point to continued evolution in basin exploration, field development and energy transition. 

CONCLUSION: SETTING A NEW STANDARD FOR SUBSURFACE INSIGHT 

Recent achievements in real-time, high-definition imaging-while-drilling show that a new foundation for formation evaluation is now being applied in field operations. By eliminating the traditional trade-off between drilling speed and subsurface clarity, these systems help operators drill faster without compromising operational value: shorter cycle time, fewer unplanned delays, and higher-confidence placement and completion decisions that protect well productivity.  

The major Middle East project stands as proof. The deployment enabled more than high-speed drilling—it improved the decision cycle and reduced uncertainty at the moments that matter most. Three takeaways stand out: (1) speed without sacrifice—high ROP does not have to mean lower insight; (2) certainty that compounds—better real-time understanding improves steering, pressure management, and completion confidence; and (3) integration that accelerates value—multi-stream workflows reduce handoff delays and help teams act on a common, trusted subsurface picture. For asset managers and well delivery teams alike, intelligent imaging brings the subsurface into step with the pace of execution and the economics of modern development. 

FRANCOIS VAN VLIET is the product champion for Geosteering & Reservoir Mapping and Geology at SLB, based in Houston, Texas, where he manages technology portfolios and drives strategic growth for a wide range of advanced formation evaluation and geology services. Mr. Van Vliet holds Bachelor of Science and Master of Engineering degrees from Cornell University, and has a robust background in engineering, operations and global supply chain management.