This paper describes geological and petrophysical evaluation of a new structure of a mature field to evaluate the reservoir potential in unproduced reservoir zones. The well was drilled in a carbonate with variations in rock quality and with minor subfaulting occurring. Gamma ray (GR), resistivity, density, neutron, and image services were used in the horizontal part of the well in addition to magnetic resonance (MR). To achieve the best possible real-time wellbore placement, reservoir navigation and continuous follow-up on the horizontal log interpretation were performed during drilling.For the first time, a low-gradient-MR-while-drilling technology was deployed in a virgin carbonate horizontal well on the Norwegian Continental Shelf. The MR service was run to obtain porosities (including partitioning of movable and bound fluids), hydrocarbon (HC) saturations, and permeability estimates. Fluid saturations based on traditional methods and the MR were evaluated and compared by core data, enhancing the understanding of the measurement and the reservoir. For post-processing, the MR data were integrated and interpreted together with the other measurements performed in the well, delivering an accurate and consistent reservoir description.The first part of the horizontal part of the well was drilled with conductive drilling fluid and the latter part with nonconductive drilling fluid. Laboratory measurements for the two mud filtrates were performed to understand the influence of the two different drilling-fluid types on the MR measurements. In the absence of water-based mudfiltrate invasion, the MR data show good agreement with saturations from core, confirming the quality and reliability of the MR data.Comparison of the MR T 2 distributions and volumetrics with image data indicates that even fine variations in rock quality and lithology are reliably resolved by the MR data. Before logging, old core data were used to refine the constants used in the Timur-Coates MR permeability equation, which quantitatively tracks changes in reservoir quality. The values were calibrated when Timur-Coates constants were derived from the well's core plugs.