Retina at-bit imaging provides precise measurements at the critical point of first contact between the drill bit and the formation. (Image source: SLB)

SLB has launched Retina at-bit imaging, which converts measurements taken at the drill bit into detailed, high quality borehole images

Successfully tested in the Middle East, Retina at-bit imaging provides precise measurements at the critical point of first contact between the drill bit and the formation, providing unsurpassed image clarity in large hole sizes as drilling commences and the borehole diameter reduces progressively toward the reservoir section, thereby enabling identification of formation characteristics to optimise drilling efficiency, formation evaluation and safety.

It works by using a PDC drill bit tailored with the latest design, architecture and cutter technologies to accommodate sensors for measuring forces at the bit face. It captures formation details to visualise and characterise layers, bedding dips, thin beds, fractures, and textural variations without interference from any type of drilling fluid. The raw data is processed to create a high-resolution borehole image for formation characterisation and rock properties qualification. High-resolution images are important for geological characterisation from the outset of drilling, revealing potential well-related expenditures such as mud-loss zones, hard drilling intervals and stuck-pipe events — which can add days to complete the well, incur non-productive time, and increase safety risks.

Retina addresses the limitations of traditional imagers, which are often restricted by operational factors like drilling fluid type and wellbore damage, and often not usable in the reservoir access intervals due to borehole size limitations.

Field test data from land operations in the Middle East have demonstrated Retina's versatility and effectiveness. In one field test in the Middle East, Retina revealed the presence of fractures and vugs (small cavities or pores within the rock) in carbonate formations, providing critical information for predicting and preventing mud losses. During another field test, the tool also provided high-resolution images of stylolites, which act as pressure barriers, allowing for a better understanding of productive zones.

“Retina provides an unparalleled view of the formation and its characteristics downhole, enabling better-informed decisions from the start,” said Cecilia Prieto, president, Well Construction, SLB.

“This leading-edge technology marks a significant advancement in borehole imaging, providing drillers with critical insight in situations where it was previously impossible. With imaging at the bit, before the formation is affected by drilling fluids, the exceptional resolution unlocks new opportunities around drilling, fluid management, and completions, leading to significant risk reduction and production optimisation.”

The service helps operators to anticipate and react to formation changes, optimise well placement, and maximise asset value. (Image source: Halliburton)

Halliburton has launched EarthStar 3DX, a 3D horizontal look-ahead resistivity service which provides operators with geological insights into horizontal wells up to 50 ft before penetration by the bit

Positioned just 3m from the bit and integrated with the iCruise rotary steerable system, the service has the capability to gather real-time data, allowing operators to identify hazards and make informed decisions, helping them to anticipate and react to formation changes, optimise well placement, and maximise asset value. Early intervention mitigates wellbore instability challenges and facilitates safe and efficient operations for customers.

The EarthStar 3DX service detects geological changes in front of the bit and around the wellbore. Mapping geological changes in real time provides operators with the guidance to proactively adjust the well path earlier, before reaching formation changes. Early actions keep the wellbore in the most productive zone to reduce reservoir exits, increase net-to-gross ratios, and improve production efficiency.

In high-angle, horizontal, and extended-reach wells, the EarthStar 3DX service helps avoid unexpected geological or fluid changes that can lead to wellbore instabilities and costly corrections. The service detects hazards, such as formation changes, faults, or fluid boundaries, ahead of the bit before they impact drilling. Early trajectory adjustments help reduce the risk of wellbore instability and costly sidetracks to ensure a safer, more efficient drilling operation.

The EarthStar 3DX service offers detailed conventional resistivity readings that support in-depth petrophysical analysis of the reservoir. Phase shift and attenuation resistivity are measured over three spacings at two frequencies using an array of electromagnetic sensors and a 24-inch crossed-antenna spacing. The combination of digitally compensated resistivity with formation anisotropy measurements near the bit drives early fluid characterisation and a more accurate water saturation calculation to improve reserves evaluation.

“EarthStar 3DX service is the latest example of Halliburton’s leadership in reservoir mapping technology,” said Jim Collins, vice president, Sperry Drilling, Halliburton.

“True to our value proposition, we customise our subsurface and drilling solutions to maximise asset value for our customers. By mapping geological variations before they are encountered, operators can adjust well trajectories to minimise risk, improve wellbore placement, and increase reservoir contact.”

3M Ceramic Sand Screens have saved PHM up to 50% cost. (Image source: Adobe Stock)

Material science and technology provider, 3M, has released via Offshore Network a case study illustrating how an Indonesian oil and gas corporation Pertamina Hulu Mahakam (PHM) deployed Ceramic Sand Screen to cost effectively unlock marginal field assets 

While coiled tubing-deployed chemical sand consolidation (SCON) or slickline deployed through tubing metallic screens are the conventional approaches to sand control at PHM, they are limited by its operating envelope and technical constraints. There is a need identified to unlock production with a change in filter media material.

3M Ceramic Sand Screens have saved PHM up to 50% cost over SCON solution and delivered 200% higher productivity than through tubing metallic screen solution by integrating 3M advanced ceramic materials into a sand screen assembly.

Assets like in Tunu and Peciko, reservoirs are marginal and multi-layered sand series which are highly unconsolidated and poorly sorted sands with an average of 20 to 30% porosity. 3M Ceramic Sand Screen have been initially trialed in these conditions and enabled in optimising sand control completions.

Within a span of 4 years, more than 80 wells in various fields of PHM have been successfully replicated.

Download the case study to learn about:

*How 3M solution has impacted to unlock production from marginal assets

*How material change enables optimised and cost-effective sand control completions

*How 3M material science empowers and contributes to their energy customers to develop improved, safer and more sustainable solutions

Click here to learn more.

Claus Reimers, chief product and technology officer at Akselos. (Image source: Akselos)

The American Bureau of Shipping and Akselos S.A., provider of structural performance management software have completed a joint technical assessment for structural digital twin technology, enabling more accurate and reliable assessments of structural integrity for FPSOs

The digital twin solution can reduce inspection and maintenance costs by up to 33%, minimising both planned and unplanned downtime by predicting stress and fatigue before failures occur, and enhancing safety by limiting human exposure in hazardous operational areas. This ultimately saves millions of dollars by extending FPSO life and minimising production losses.

Akselos’ SPM software provides a high-fidelity, near real-time digital twin of the entire FPSO. By combining inspection records, metocean conditions, and cargo operations into one dynamic model, operators have access to a live, continuous view of structural performance. This facilitates real-time monitoring, identification of stress concentrations, and on-demand fatigue analysis to support data-driven maintenance and risk-based inspections.

When combined with ABS’ Condition Manager and Eagle Twin inspection data management and condition tracking software tools, the Akselos software is capable of monitoring real time load and condition information within a digital twin framework that enables full life cycle support of an offshore asset. Akselos’ SPM software also integrates with ABS’s Eagle Unified suite, providing operators with a unified platform for asset performance management and class compliance.

“This collaboration reinforces the role of high-fidelity digital twin technology in the future of offshore structural integrity management,” said Matt Tremblay, senior vice president, Global Offshore at ABS. “By combining real-time operational data with advanced simulation, Akselos is enabling a more predictive and performance-based approach to asset management—fully aligned with the industry’s drive toward safer, more efficient operations.”

“This joint work confirms the robustness of our software and reinforces the growing momentum for digital transformation in offshore oil and gas,” said Claus Reimers, chief product and technology officer at Akselos. “We enable operators to simulate the structural integrity of the entire FPSO in real time and at full fidelity—supporting smarter, safer decisions across the asset lifecycle.”