DUG Elastic MP-FWI Imaging is a unique approach to seismic processing and imaging. (Image source: DUG Technology)

Supercharge legacy data with DUG Elastic MP-FWI Imaging by using the entire wavefield, including all free-surface multiples and converted waves, as high-octane signal.

DUG Elastic MP-FWI Imaging is a unique approach to seismic processing and imaging which turns the traditional paradigm on its head. It replaces not only traditional processing and imaging workflows, but also the subsequent inversion workflow for elastic rock properties.

The traditional processing workflow involves the testing and application of dozens of steps such as deghosting, designature, demultiple and regularisation, which are all designed to overcome the limitations of conventional imaging. These workflows are complex, subjective, and very time-consuming due to their serial nature and they rely on many assumptions and simplifications. All of these issues impact the output data quality. The resulting, primary-only data then undergoes a similarly complex model-building workflow to derive an estimate of the subsurface velocity, which is used for depth imaging. Post-migration processing is performed before the pre-stack reflectivity undergoes another workflow to derive rock properties that feed into quantitative interpretation, also relying on simplifications of the actual physics. As a result of these workflows, projects can take many months to years to complete.

Multiples are normally considered as problematic noise, however they illuminate the subsurface in complementary ways to primary reflections. When imaging with primaries and multiples the subsurface is sampled far more completely, and with a wider range of angles — constraining the inverted reflectivity, rock properties and attenuation.

Elastic MP-FWI Imaging accounts for both compressional and shear waves, handling variations in seismic wave dynamics as a function of incidence angle, including in the presence of high impedance contrasts and onshore near-surface geological complexity. Multiples and converted waves are now treated as valuable additional signal, increasing sampling, resolution and constraining the inverted parameters.

The figure above shows a comparison of the reflectivity derived with DUG Elastic MP-FWI Imaging using raw field data, versus a conventional LS-RTM workflow using extensively pre-processed input. This legacy dataset was acquired in 2006 on the Australian North West Shelf. This region contains rapidly changing shallow velocity variations due to localised channel features and carbonates. The MP-FWI imaging results demonstrate an increase in spatial resolution — the channel features, reservoir flat spot, and complex faulting are sharper and more clearly delineated.

A complete replacement for traditional processing and imaging workflows is no longer a stretch of the imagination. Visit dug.com to see more outstanding DUG Elastic MP-FWI Imaging results.

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DUG Elastic MP-FWI Imaging leaps entire workflows in a single bound, delivering unsurpassed imaging and high-resolution rock properties from field-data input. Superior outputs, in a flash!

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The valve is being piloted in both onshore and offshore environments. (Image source: Adobe Stock)

Flow control specialist Oxford Flow has started commercial trials of its ES stemless control valve with ADNOC

The ES valve is proven through third-party testing to eliminate fugitive emissions. With no stem or external actuator, its compact design removes common failure points, reduces maintenance requirements and enables a significantly smaller footprint. This makes it simpler to install and service, more reliable in extreme environments, and well suited to high-performance applications across upstream and downstream operations - supporting operators to cut emissions without compromising on efficiency or durability.

 The ES valves are currently being piloted both onshore and offshore at key production fields Upper Zakum and Das Island, the aim being to demonstrate the valve’s ability to eliminate fugitive emissions while supporting ADNOC’s ambitious decarbonisation targets.

This pilot marks a significant step in Oxford Flow’s expansion in the Middle East and reinforces the company’s aim to partner with operators committed to real-world deployment of decarbonisation technologies. Working alongside ADNOC in live field conditions provides a powerful opportunity to demonstrate the commercial and environmental benefits of next-generation valve technology at scale.

Neil Poxon, CEO at Oxford Flow, said, “Leaking valves are a major, often overlooked, source of emissions. By replacing them, operators can make fast, material progress in decarbonising both onshore and offshore systems. It’s a significant step forward to now see ADNOC piloting the ES valve in live operations.”

With the growing focus on reducing emissions, Oxford Flow’s valve technology is already in use in a number of markets including North America. 

technology enables more efficient and reliablThe technology enables the acquisition of formation evaluation measurements in any well condition. (Image source: SLB)

SLB has introduced the OnWave autonomous logging platform, which has already been deployed successfully in the Middle East and could potentially revolutionise formation evaluation

The first-of-its-kind technology enables more efficient and reliable acquisition of formation evaluation measurements in any well condition — even in historically challenging tight gas and unconventional reservoirs — autonomously acquiring multiple, high-fidelity measurements downhole, without the need of a wireline unit, and wireline cable. Its cable-free design takes less than half the time to deploy compared with conventional wireline platforms, while enabling drill pipe rotation and mud circulation during logging operations, to enhance well safety and minimise stuck pipe events.

The OnWave platform executes tasks downhole that would typically be performed manually by engineers at surface, including borehole measurement acquisition and data quality checks. It also verifies the tool’s position and functionality downhole through constant communication with surface, assuring confidence in the data acquisition quality and avoiding remedial logging runs.

The acquired data is streamed to the SLB collaborative cloud, where it undergoes intelligent processing and interpretation. This data can be viewed on demand, for real-time insights and informed decision making.

OnWave has been deployed successfully across different regions, including in the USA and Middle East, demonstrating significant efficiency gains in complex well trajectories. In South Texas, the platform reduced the landing time to total depth of the well from hours to just 27 minutes — a 70% reduction compared with conventional deployment techniques. Processing of the measurements at surface provided high‑quality integrated petrophysics and acoustic insights, enabling the E&P operator to improve the stimulation and completion designs and derisk asset field development.

“The OnWave platform marks the beginning of a new era in formation evaluation,” said Frederik Majkut, president of Reservoir Performance, SLB. “By streamlining how we gather high-fidelity measurements downhole, we are opening up key opportunities for our customers to integrate data-driven decision making into their workflows across the well life cycle — from exploration through to production and recovery.”

The system combines automation, real-time intelligence and advanced geological modelling to optimise well placement. (Image source: Halliburton)

Halliburton has launched LOGIX automated geosteering, a part of the LOGIX automation and remote operations family of solutions, that optimises geological interpretation and well placement

The service redefines geosteering precision by combining automation, real-time intelligence, and advanced geological modelling to optimise well placement, maximise recovery, and improve operational efficiency.

The system continually projects ahead to detect geological variations along the planned well path and updates it accordingly, reducing geological uncertainty and enabling timely and accurate drilling decisions to keep the wellbore in target zones and maximise recovery.

LOGIX automated geosteering integrates real-time resistivity, seismic, and formation imaging data to improve geological mapping and optimise reservoir exposure through automated trajectory control. The automated real-time boundary detection continuously updates the geological model to improve model accuracy and enable precise, real-time trajectory adjustments to stay in the reservoir. LOGIX automated geosteering uses real-time resistivity inversions and imaging data to identify new pay zones, define new targets, and make informed well placement decisions to optimise reservoir contact. It delivers real-time visualisation of key reservoir characteristics, including thickness and fluid contacts.

Automated calculations accelerate the time between detection and action to improve consistency and minimise errors. This can improve wellbore tortuosity, and accelerate well delivery.

The integration of LOGIX automated geosteering and LOGIX auto steer allows a smooth transition from well path updates to real-time drilling control to improve operational efficiency. Automated geosteering analyses and incorporates the data from offset wells, geological and seismic data, and real-time drilling and LWD data to improve subsurface insight and enable faster decision making.

The service can be integrated with the DecisionSpace earth modeling software to ensure automated data processing and uniform geological interpretations across different projects and teams.

“LOGIX automated geosteering creates value for our customers with services that provide subsurface and drilling customisation. We accomplish this with the optimisation of well placement and recovery,” saidJim Collins, vice president, Halliburton, Sperry Drilling.