The new deals, valued at approximately $2.9 billion over 3 years, cover services for liner hangers, downhole monitoring, and additional completions on the NCS. Called Eelume, the underwater drone will perform subsea inspection, maintenance, and repair work. A project of “firsts,” Equinor’s Aasta Hansteen spar platform began producing gas on 16 December, opening a new region for gas export to Europe and the UK. Aqualis Offshore and Aker BP have signed a 5-year frame agreement. Aker was awarded 23 new production licenses by the Norway Ministry of Petroleum and Energy on 16 January.
In a $60 to $70 oil environment, the subsea market is poised to grow around 7% annually up to 2025. But a significant portion of this activity is at risk if the price of Brent crude falls to $50 per barrel. The subsea operations company said its most recent campaign is the first fully unmanned offshore pipeline inspection completed “over the horizon,” surveying up to 100 km from the shore. The subsea tieback is expected to start up in 2021. The Neptune-operated project is on track to start drilling later this year, with first oil scheduled for the end of 2020.
The subsea operations company said its most recent campaign is the first fully unmanned offshore pipeline inspection completed “over the horizon,” surveying up to 100 km from the shore. One of the largest industrial projects in the UK in recent years, Mariner marks Equinor’s first operated field on the UK Continental Shelf. It is expected to produce 70,000 BOPD at peak rates. The Norwegian Petroleum Directorate has given clearance to start up facilities at the North Sea field, which straddles the line between the UK and Norwegian sectors. Lundin reports that the hookup and commissioning of installed facilities at the large North Sea field is progressing as planned.
At nearly 3,000 tonnes, the company said its lift of an FPSO module was one of the heaviest land-based crane lifts ever performed. ALE was contracted to lift six modules for Total’s FPSO module integration project in Nigeria. The subsea tieback is expected to start up in 2021. This is Shell’s second major development on a tieback in the US Gulf of Mexico, following Kaikias’ startup in May. Lundin reports that the hookup and commissioning of installed facilities at the large North Sea field is progressing as planned.
How Are Oil and Gas Firms Approaching Digital Investment, Implementation? Leveraging new digital technology, Equinor recently opened two onshore support centers in Norway. All of the firm’s operated fields on the Norwegian Continental Shelf will be managed from onshore facilities by 2021. Digital technologies have become an integral part of capital budgets for oil and gas operators. This fact is driven home by a recent survey in which 9 in 10 executives from the industry in the US and abroad said they plan to increase spending on digital tools over the next 2 years.
Egil Hustvedt, a platform manager, demonstrates the digital twin of the Aasta Hansteen field. Equinor reached another milestone in its digital transformation with today’s official opening of two new onshore support centers that will centralize much of its offshore exploration and production activities. Located in Bergen, the company says that the centers have already helped boost production and improve safety. The expectation is that the digitally enabled centers and their multidisciplinary staff will create more than $2 billion in new value from 2020-2025. The integrated operations center saw its first test in September as it was connected to the Grane, Gina Krog, and Åsgard fields.
The mating of the spar’s topside and hull was completed in December 2017. Equinor and its partners started production on 16 December from the Aasta Hansteen gas field in the Norwegian Sea. Gas from the field was available on 17 December to the market, opening a new region for gas export to Europe and the UK via the Polarled pipeline to the Nyhamma gas processing facility. It is also the first spar in Norway and the first in the world to contain condensate storage, with storage capacity of 25 000 m3. The area is characterized by particularly harsh environmental conditions.
In 2016, Wintershall Norge AS and PL847 partners were awarded a production license covering blocks 6706/5 and 6706/6 of the Norwegian Continental Shelf. The area is located in the Vøring Basin on the Nagflar Dome, north of the Hel Graben. The Aasta Hansteen gas development is located approximately 60 kilometres to the South.
Four Upper Cretaceous prospects have been identified in addition to the Hvitveis discovery. Hvitveis is a faulted 4-way dip closure. Marisko, and the three other prospects are tilted fault blocks. The proven reservoir in Hvitveis and the targeted reservoir in the prospects are sands of the Upper Cretaceous Nise Fm level (Figure 1).
All recent discoveries at the Nyk High and Vema Dome show flat spots or amplitude anomalies related to hydrocarbon fill. In the Greater Aasta Hansteen area, the reservoir properties are generally good, with porosity values exceeding 30% and permeabilities in the Darcy range. However, in the Hvitveis discovery well 6706/6-1, the reservoir properties are much poorer with an average porosity of 15% and estimated permeability values ranging from very tight to 5mD. These poor reservoir properties could partly explain why no obvious flat-spot or hydrocarbon related amplitudes anomalies were observed in Hvitveis or in the four other prospects on the vintage seismic at the time of the application.
The initial part of the work program was a re-processing of the available 3D seismic to identify potential direct hydrocarbon indicators and allow a more detailed interpretation and understanding of reservoir distribution. To address these goals, a Pre-Stack Depth Migration was run using a dataset re-processed with the latest de-multiple and de-ghosting technology.
Presentation Date: Monday, October 15, 2018
Start Time: 1:50:00 PM
Location: 206A (Anaheim Convention Center)
Presentation Type: Oral
In this paper we propose a new workflow to perform Petrophysical Joint Inversion (PJI) of surface to surface seismic and Controlled Source ElectroMagnetic (CSEM) data, to recover reservoir properties (clay volume, porosity and saturation). Seismic and CSEM measurements provide independent physical measurements of subsurface that complement each other. In the case of well-logs, the basis of the PJI training dataset, taking advantage of such complementarity is straightforward. Indeed, elastic and electric measurements of earth properties sense the same earth volume at much the same scale. When applying the training dataset to the surface data derived geophysical attributes, the order of magnitude gap in between the scale at which those elastic and electric attributes represent the earth undermines dramatically PJI validity. Various CSEM inversion constraining methods (regularization breaks, prejudicing, use of an a priori model etc) help to reconcile seismic and CSEM resolution, but they are usually proven to be insufficient or inaccurate. In addition to these methods, we suggest adding a further downscaling step, so the recovered electric attribute resolution can be adequate with respect to the seismic one, hence fit for purpose. Such downscaling is designed to be consistent in electrical attribute space via transverse resistance within a rockphysics framework. The workflow will be demonstrated on a case study.