Abstract The growing importance of subsurface carbon storage for tackling carbon emissions requires an accurate characterization of potential reservoirs to understand their capabilities. In this context, the use of legacy data originally acquired in the last fifty years for scientific projects and petroleum exploration and production activities would represent a suitable cost-effective solution and help to maximize the value of this extended national asset. Core material represents the only direct observation of subsurface deposits and must be preserved from the current disposal process related to the decommissioning of hydrocarbon fields. In this contribution, a suite of samples from core material stored at national (i.e. British Geological Survey) and local (i.e. Department of Earth Sciences, Royal Holloway, University of London) core repositories, previously characterized at the micro scale using X-ray micro-computed tomographic (μCT) imaging are discussed. Using this technique, it has been possible to investigate how pore and grain geometries control crucial features of a suitable reservoir such as porosity and permeability. The aim of this contribution is to describe the methodology behind digital image analysis (DIA) following μCT imaging applied to core material. We show how DIA can be used to provide significant measures of reservoir suitability when making initial assessments of storage reservoirs, without the need for expensive and time-consuming analyses.

Abstract Over the last 50 years, the North Sea and the Atlantic Margin and, more recently the Barents Sea, represented key study areas for academic and professionals interested in the exploration for and production of hydrocarbon from the Earth's subsurface. Nowadays, these areas may play a major role in the so-called ‘energy transition’, with the energy industry now seeking to reduce emissions related to hydrocarbon consumption, and leading the development of carbon capture and storage activities, such as the Northern Light project ( https://northernlightsccs.com ). Consequently, there is an increasing interest in advancing our knowledge regarding the stratigraphy, sedimentology and tectonic development of the North Sea, Atlantic Margin and Barents Sea with a cross-border approach.

Abstract Deep-marine gravity-driven deposits represent one of the more investigated depositional systems owing to their potential interest as targets for exploration and carbon capture and storage activities, as well as an important record of the depositional history of a basin through time. Although the Halten Terrace (Norwegian Sea) is one of the main successful exploration areas, we still have poor understanding of the post-rift Cretaceous interval. Here, 3D seismic reflection and borehole data are integrated to investigate the stratigraphic distribution and sedimentological characteristics of the Cenomanian–Turonian intra Lange Sandstones in the Gimsan Basin and Grinda Graben. The Lange Fm records the deposition in a deep-marine environment of a 1000 m-thick shale unit punctuated by gravity-driven coarse-grained sandstone intervals that are tens of metres-thick and sourced from the Norwegian mainland. The presence of gravity-driven deposits and the deep-marine setting are supported by seismic interpretation, architectural elements and the facies analysis of cored material acquired within the studied stratigraphic interval. Borehole data indicate the presence of both turbidites and hybrid-event beds rich in mud content. The results of this study have implications for understanding the distribution and reservoir potentiality of the Late Cretaceous Lange Fm in the Halten Terrace.

Abstract The North Sea has reached an ultra-mature state as a petroleum basin, entering a phase of infrastructure-led exploration in an attempt to extend the economic lives of the main fields and reduce the rate of production decline. At the same time, the transition to a future low-carbon use of the basin is also in progress. As the papers in this volume demonstrate, in order to find, appraise and develop the mostly smaller near-field opportunities as well as making sure to grasp the opportunities of the near-future energy transition, a regional understanding of the North Sea is still critical. Even more so, a cross-border approach is essential because: (1) some of the plays currently being targeted have a clear cross-border element; (2) it allows a comparison of stratigraphic names throughout the entire basin; and (3) it enables explorers to learn lessons from one part of the rift to be applied somewhere else. This volume offers an up-to-date ‘geology-without-borders’ view of the stratigraphy, sedimentology, tectonics and oil-and-gas exploration trends of the entire North Sea Basin. The challenges associated with data continuity and nomenclature differences across median lines are discussed and mitigated. Examples of under-exploited cross-border plays and discoveries are discussed.