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As demonstrated by recent exploration success, Viridien’s Northern Viking Graben (NVG) seismic survey in the Northern North Sea has already proven to be a valuable exploration tool. Thanks to the high-quality seismic data in this geologically challenging area, prospects are better defined, allowing for qualified drill decisions. In 2024, Viridien applied the latest seismic acquisition and imaging technology to add a northern extension, known as NVG24, to its current coverage over the NVG so that it now extends into the Møre Basin and Møre Platform in the Norwegian Sea. A glimpse of the early fast-track data from NVG24 is shown in the foldout juxtaposed with fully imaged data from the NVG EW coverage. The upcoming NVG24 final data will be of the same high quality and reveal structural and stratigraphic details at the Manet Ridge, Marulk Basin, Gnausen High and the Møre Platform.

This article focuses on an area of the Ivorian part of the Tano Basin where no drilling has yet taken place. It describes the interpretation of a new multi-client BroadSeis™ 3D seismic survey covering this unexplored area, which has provided the basis for a geological review.

Viridien drills down into the prospectivity of Côte d’Ivoire’s Tano Basin while sharing the final data from its multi-client CDI23, 3D PSDM re-imaging project.

This case study demonstrates how a long-offset, wide-azimuth four-component OBN survey, in combination with Full-Waveform Inversion, can be used to produce detailed 3D images and a geobody of the Sleipner CO2 plume that can be used for quantitative analysis.

Our Head of Geoscience explains how Viridien’s latest seismic technologies, such as full-waveform inversion and the Sercel Tuned Pulse Source (TPS), are delivering outstanding early-out results on this next-generation multi-client program.

A comprehensive seismic reservoir characterization study was conducted in a gas field in Argentina, utilizing geostatistical AVA seismic inversion to generate inputs for reliable static models and dynamic simulation. The study encompassed a range of disciplines, including petrophysics, rock physics modelling and geostatistical AVA seismic inversion followed by effective porosity co-simulation. The key advantage of the geostatistical inversion method lies in its ability to integrate all available data, including wells, seismic, and geological knowledge, and generate reasonable outcomes that honour all inputs. Notably in this study, the use of 3D prior proportions for geostatistical inversion proved to be crucial for better characterization of litho-facies across the area, outperforming the 1D prior proportions approach. The results of the geostatistical inversion, conceptual depositional model, and previous seismic attributes study showed significant consistency, increasing confidence in the outcomes of the geostatistical inversion. The results of this study will be used to build static models of the field, enabling the estimation of in-place gas volume and its associated uncertainty. These models will also serve as input for dynamic simulations for future development of this field.

Building on our earlier Big Data paper at OTC in May 2015, this article in JPT October 2015 continues our push to demonstrate the use of Big Data in an Oil & Gas context. Well data from the UKCS were analysed to identify "bad hole" sections.

The heterogeneity in geological properties of carbonate rocks makes their acoustical behaviour more difficult to model and predict than siliciclastics. This uncertainty in prediction normally is attributed to their pore structure complexity and heterogeneity. Pore structure in carbonate is a result of the place they are deposited combining with subsequent post-depositional processes to form the final carbonate rock. Carbonates can form in different depositional environments and subsequently can undergo into various diagenesis regimes. This combination along with their chemically active mineralogy makes them susceptible for complex and heterogeneous pore structures. This study investigates variation of carbonates depositional environment on their velocity behavior. It, furthermore, uses this information to quantify a more comprehensive pore model for carbonate rocks. This geology dependent workflow is tested on a number of carbonate core-plugs from two exploration wells with ultrasonic measurements. The results confirm application of this workflow for defining a more comprehensive pore model compared with the routine approach using only Wyllie time average by defining maximum two pore types. This study uses another reference curve from depositional environment in addition to the routine approach to derive a more general (geology oriented) pore aspect ratio spectrum.

A primary motivator for users to turn to HPC resources in the cloud has been to provision temporary capacity for jobs that surge and exceed the available utilization of on-premises systems. While that is still a driver for consuming HPC cloud resources, an increasing number of complex, computationally challenging jobs are capable of being run entirely in the cloud, particularly with the focused approach taken by HPC-as-a-service (HPCaaS) cloud providers.