The major challenge facing society in the 21st century is to improve the quality of life for all citizens in an egalitarian way, by providing sufficient food, shelter, energy and other resources for a healthy meaningful life, whilst at the same time decarbonizing anthropogenic activity to provide a safe global climate. This means limiting the temperature rise to below 2 C. Currently, spreading wealth and health across the globe is dependent on growing the GDP of all countries. This is driven by the use of energy, which until recently has mostly derived from fossil fuel, though a number of countries have shown a decoupling of GDP growth and greenhouse gas emissions from the energy sector through rapid increases in low carbon energy generation. Nevertheless, as low carbon energy technologies are implemented over the coming decades, fossil fuels will continue to have a vital role in providing energy to drive the global economy. Considering the current level of energy consumption and projected implementation rates of low carbon energy production, a considerable quantity of fossil fuels will still be used, and to avoid emissions of GHG, carbon capture and storage (CCS) on an industrial scale will be required. In addition, the IPCC estimate that large scale GHG removal from the atmosphere is required using technologies such as Bioenergy CCS to achieve climate safety. In this paper we estimate the amount of carbon dioxide that will have to be captured and stored, the storage volume and infrastructure required if we are to achieve both the energy consumption and GHG emission goals. By reference to the UK we conclude that the oil and gas production industry alone has the geological and engineering expertise and global reach to find the geological storage structures and build the facilities, pipelines and wells required. Here we consider why and how oil and gas companies will need to morph into hydrocarbon production and carbon dioxide storage enterprises, and thus be economically sustainable businesses in the long term, by diversifying in and developing this new industry.
Harstad is not the end of the world but you can see it from there, a real frontier area. From this area above the polar circle exploration and development has been lead in the Norwegian and the Barents seas. Exploration wells are being drilled in the now opened former disputed areas, was it worth the fuss? "Technology forum about the Arctic in the Arctic" has always been the slogan of the SPE Northern Norway Workshop. In March 2019, this two-day biannual workshop will raise the stakes, broaden the scope, and showcase all the latest success in the region.
The offset dependent variation of the acoustic impedance has been used throughout the lifecycle of oilfields to discriminate pressure and saturation differences. While there are many ambiguities caused by overburden, tuning, morpho- and lithological effects the analysis provides additional insights to the distribution of pore pressure and fluids in a given rock physics framework. An experimental design assessing the sensitivity of AVO effects in a rock physical context is proposed. The methodology is applied to a planned CO2 injection test at the Svelvik CO2 Field Laboratory, South of Oslo, Norway. The geology is inspired from a recent site characterization (Bakk et al., 2012) and is supplemented with different conceptual features. The information present for the site is translated into a scenario based ensemble of static models.
A detailed understanding of the underlying rock physics model is required not only to design the monitoring campaigns before injection, but will provide the basis to alter the underlying parameters defining the magnitude and sensitivity of simulated and measured acoustic impedances. Distinguishing pressure and saturation related changes of the acoustic impedance is subject to the sensitivities of the properties used to derive the underlying seismic P- and S-velocities as well as densities. These uncertainties can induce a non-negligible variability in the footprint of a seismic image of the CO2 plume. This allows to explain subtle heterogeneities of highly simplified simulations. Designing cost efficient surveys to obtain an effective coverage of the injected CO2 and discrimination of fluid and saturation related pore effects require a rigorous approach in the quantification of the rock physical properties upfront.
Presentation Date: Wednesday, October 17, 2018
Start Time: 9:20:00 AM
Location: Poster Station 3
Presentation Type: Poster
The capacity for the storage of carbon dioxide in saline aquifers remains enormous. Of all geological storage media, it provides the best storage capacity. In this study, the potential of the Shuaiba Formation, in the Falaha syncline, for geologic sequestration is assessed. A regional geo-model was built using seismic and well data (logs, cores) from the Falaha Syncline and nearby fields. The model was built to honor the heterogeneity and sequence stratigraphy of the Shuaiba carbonate platform using a five-order hierarchical conceptual model of the Shuaiba formation that merged sequence architecture and reservoir architecture together. This was achieved by honoring lithofacies, facies association packages and rock types in their corresponding depositional settings in the sequence framework. Dynamic simulations were then conducted on an upscaled geological model using a compositional reservoir simulator to determine its storage and flow capacity, plume migration pathways and to understand the physics of the fluid flow in the aquifer. Simulations are made to be conservative thus accounting for structural/stratigraphic, solubility (dissolution in resident brine) and residual trapping without accounting for the slower mineral trapping process. Detailed sensitivity studies were conducted during the simulations to understand the effect of well parameters, rock and fluid properties amongst others on the storage capacity in the aquifer. Simulation results indicate that significant volumes could be stored in the aquifer and could take a significant amount of time before the injected gas reaches the surrounding hydrocarbon producing fields. This study provides the first full field approach to characterize and to quantify the suitability of the identified aquifer for long term storage of carbon dioxide in the subsurface of UAE.
In certain offshore shallow water production areas in cold regions the sea conditions are characterized by first year and potentially multi-year ice features. Unlike some other arctic regions, which are characterized by icebergs, there are regions where no icebergs occur. However, gouges are formed by rafted ice, pressure ridges, and multi-year ice from the polar pack that forms deep keels. Ice gouging of the seabed in these areas is caused by winds, currents and waves driving the ice sheet containing these ice keels.
As more reserves are being found in shallow water arctic and sub-arctic environments, there is a need to determine how best to develop these resources cost effectively. See
This paper discusses a novel design to best protect the subsea template and its mechanical equipment. Furthermore, this paper outlines the process undertaken for designing a subsea drilling and production template and protective structure by encasing the template within a protective structure that is placed in an armored excavation, or "Glory Hole", to prevent sand intrusion and ice keel penetration.
To protect a drilling and production template in shallow water, an enclosed structure was required to be embedded in the soil at the bottom of a Glory Hole with a full-time domed protection cover to protect from ice and soil entrance. Slotted doors allow jackup access to the template during drilling. Operation of the Wellheads contained within the Subsea Template is remotely controlled by a subsea cable containing electrical, hydraulic and fiber optic cables and tubes. The operation of the facilities can be monitored and controlled at the Command and Control Center located onshore and connected to the offshore template by the control cable.
The paper describes the technology challenges for year-round oil and gas production on 74 N in the Norwegian part of the Barents Sea. The northernmost blocks in the ongoing 23rd licensing round on the Norwegian Continental Shelf (NCS) are at 74 N and the physical environment in this area differs from other areas on the NCS where there are oil and gas production today. Firstly the paper briefly describes the physical environment in the Barents Sea, secondly it describes the technology challenges given yearround production. There are identified eleven key technologies which are enabling year-round oil and gas production in the Barents Sea. The technologies are grouped into which technologies that are considered necessary for enabling production, and which can enhance the production in either reducing CAPEX and OPEX or increasing production. All identified technologies have a relatively high technology maturity level. This means that in many cases technologies have already been applied other places in the world (e.g. Canadian Grand Banks) and could be adopted with minor modifications. In some other cases, technologies would have to be further tested at full scale before they could be applied.
This study implements a multidisciplinary approach to porosity (PHIE), shale volume (Vsh) and sand probability estimation from prestack angle gathers and petrophysical well logs. A rock physics feasibility study revealed the optimum petrofacies discriminating ability of extended elastic impedance (EEI) and PHIE. Multilinear regression analysis is then applied to the output of the simultaneous inversion of seismic data to estimate Vsh and PHIE. Probability distribution functions (PDFs) and
Presentation Date: Monday, October 17, 2016
Start Time: 1:50:00 PM
Presentation Type: ORAL
Summary In this paper, we investigate the use of spectral decomposition and facies classification on time-lapse data related to a Brazilian pre-salt carbonate reservoir. Synthetic seismic data were generated through petro-elastic modeling (PEM), which is based on a representative geological model and flow simulator dynamic properties. Reservoir pressure and saturation distributions are used that corresponds to periods of time, in which, real time-lapse seismic data will be available. The spectral decomposition method used, is based on a modified matching pursuit algorithm. At this stage, we focus on the interpretation of the spectral decomposition, mainly on geometric effects.
Nguyen, Anh Kiet (Statoil ASA) | Nordskag, Janniche Iren (Statoil ASA) | Wiik, Torgeir (Statoil ASA) | Bjørke, Astrid Kornberg (EMGS ASA) | Boman, Linus (EMGS ASA) | Pedersen, Ole Martin (EMGS ASA) | Ribaudo, Joseph (EMGS ASA) | Mittet, Rune (EMGS ASA)
Electromagnetic signals are exponentially attenuated in conductive media. Thus, marine controlled-source electromagnetic (CSEM) data where the source and the receivers are located in the water column has exponentially low sensitivity towards the deep stratigraphy, compared to the shallow stratigraphy. In addition, CSEM inversions are also highly non-linear and ill-posed. It is therefore often difficult to achieve good inversion results for the deeper part of the subsurface using gradient based inversion methods.
In this abstract, we describe a large-scale 3-dimensional anisotropic Gauss-Newton (3DGN) CSEM inversion implementation and discuss its advantages over gradient based algorithms. We also show, by synthetic and real data case studies, the large improvements in the 3DGN inversion results compared to those from the Broyden–Fletcher–Goldfarb–Shanno (BFGS) algorithm.
Presentation Date: Tuesday, October 18, 2016
Start Time: 3:45:00 PM
Presentation Type: ORAL
Environmental impact reduction is an essential component that compliments the commitment of every Oil and Gas Operator, Service provider, etc. towards the promotion of a greener environment. From the planning phase of oilfield operations, OCTG-Oil-Country Tubular Goods require the use of thread compounds (pipe dope) to protect machined surfaces from environmental corrosion, to lubricate the connections during installations and also provide sealability among other expectations. From the production, storage, preparation for operations, running and installation of OCTG, the use of thread compounds cannot be overlooked. These compounds like most Oilfield chemicals expose both personnel and environment to a harmful condition, placing all personnel involved in this value chain of material and service delivery affected one way or the other. A technologically crafted modern solution/ alternative was developed in 2003 to fully eliminate the use of these thread compounds-A Dope-Free Solution replacing both storage and running compounds (Carcagno, G., Castiñeiras, T., & Dag, J., 2007). These Dope-Free connections are equipped with a dry coating applied through a controlled industrial process. It was first developed to meet the strict environmental requirements in the North Sea. In line with the "zero discharge" policy, this dry coating applied onto threads soon demonstrated other operative, health and safety advantages as compared to the traditional thread compounds. A presentation is made highlighting the benefits with the use of the Dope-Free technology, with a focus on health, safety and environment impact during storage, cleaning, inspection, running and post running operations including waste management.