The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
- Management
- Data Science & Engineering Analytics
Filters
Feature
SPE Disciplines
Geologic Time
Conference
- ISRM International Symposium - EUROCK 2016 (1)
- Offshore Technology Conference (1)
- SPE Arctic and Extreme Environments Technical Conference and Exhibition (1)
- SPE International Conference on CO2 Capture, Storage, and Utilization (1)
- The Twenty-third International Offshore and Polar Engineering Conference (1)
Theme
Author
- Baghbanbashi, T.. (1)
- Bohloli, B. (1)
- Choi, J. C. (1)
- Farokhpoor, R.. (1)
- Fomin, Y.V.. V. (1)
- Irving, James (1)
- Kulyakhtin, Anton (1)
- Kulyakhtin, Sergey (1)
- Lindeberg, E.G.B.. G.B. (1)
- Løset, Sveinung (1)
- Marchenko, A.V.. V. (1)
- Mork, A.. (1)
- Onishchenko, D.A.. A. (1)
- Pluymakers, A. (1)
- Skilbred, Anders W. B. (1)
- Skurtveit, E. (1)
- Torsæter, O.. (1)
- Wierzba, Zuzanna (1)
- Zhmur, V.V.. V. (1)
Concept Tag
- accretion (1)
- Accretion rate (1)
- accuracy (1)
- air entrapment (1)
- air temperature (1)
- amplitude (1)
- arctic (1)
- Brine (1)
- chemical flooding methods (1)
- climate change (2)
- co 2 (2)
- coating (1)
- coefficient (1)
- construction (2)
- contingency planning (1)
- contraction (1)
- convective heat transfer (1)
- Corrosion Inhibition (1)
- Corrosion Management (1)
- cylinder (1)
- dh6 (1)
- direct shear test (1)
- dissolution (1)
- enhanced recovery (1)
- Epoxy PFP (1)
- epoxy pfp dft (1)
- equation (1)
- europe government (1)
- experiment (1)
- exposure (1)
- flexibility (1)
- flow in porous media (1)
- flowline corrosion (1)
- Fluid Dynamics (1)
- fracture (1)
- friction coefficient (1)
- generation passive fire protection (1)
- H2S management (1)
- heat flux (2)
- heat transfer (1)
- horizontal stress (1)
- ice accretion (1)
- ice accretion rate (1)
- ice density (1)
- ice salinity (1)
- in-situ stress (1)
- injection (1)
- injection pressure (1)
- injection test (1)
- interval 1 (1)
- intumescent coating (1)
- kapp toscana group (1)
- Longyearbyen (3)
- longyearbyen co 2 (1)
- materials and corrosion (1)
- migration (1)
- model 1 (1)
- model 2 (1)
- Modeling & Simulation (1)
- normal stress (1)
- Norway (1)
- norway government (1)
- norwegian journal (1)
- numerical simulation (1)
- Offshore Technology Conference (1)
- oilfield chemistry (1)
- oscillation (1)
- permeability (1)
- Petroleum Engineer (2)
- pfp 1 (1)
- pfp 2 (1)
- pfp 4 (1)
- pilot site (1)
- pipeline (1)
- Pipeline Corrosion (1)
- pore pressure (1)
- precipitation (1)
- Production Chemistry (1)
- production control (1)
- production monitoring (1)
- relative permeability (1)
- Research Site (1)
- Reservoir Characterization (3)
- reservoir simulation (2)
- Reservoir Surveillance (1)
- riser corrosion (1)
- salinity (1)
- sandstone (1)
- saturation (1)
- Scenario (1)
- shear stress (1)
- social responsibility (1)
- soil temperature (1)
- spe 166940 (1)
- steel (1)
- Subsurface Corrosion (1)
- Svalbard (3)
- Thickness (1)
- Upstream Oil & Gas (4)
- variation (2)
Genre
Geophysics
Industry
Oilfield Places
Technology
Source
File Type
Site News
Goto
No map tile layer
| Layer | Fill | Outline |
|---|
Map layers
| Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
|---|
| Fill | Stroke |
|---|---|
Collaborating Authors
Longyearbyen
Abstract Epoxy passive fire protection (PFP) products are extensively used for fire proofing of structures and assets around the world. Significant projects such as construction of large hydrocarbon processing industry (HPI) plants may require a global supply chain meaning that a structure or an assembly may be manufactured one location and assembled in another. Manufacturing, application of coatings, handling, transportation, and construction will for many large projects take place in different climates. It is therefore important that an epoxy PFP product shows excellent cold climate properties for all climate performance. This study presents mechanical properties of one newly developed and three commercially available epoxy PFP products. The flexural strain of the newly developed epoxy PFP was found to be similar or higher than the other tested products for temperatures between −50 °C and 20 °C. Further, the strength at break, i.e. at the point of fracture, of the tested epoxy PFP products was found to increase as a function of decreasing temperature. Leading to the conclusion that the newly developed epoxy PFP was more robust at especially at lower temperatures, compared to the commercially available products. An Arctic test station located outside Longyearbyen at Svalbard in Norway was used for outdoor cold climate exposure After approximately one year, it was found that a low flexibility product showed significant cracking, whereas the more robust newly developed epoxy PFP showed no visual degradation.
arctic, coating, construction, contingency planning, contraction, Corrosion Inhibition, Corrosion Management, Epoxy PFP, epoxy pfp dft, europe government, exposure, flexibility, flowline corrosion, generation passive fire protection, H2S management, intumescent coating, Longyearbyen, materials and corrosion, norway government, Offshore Technology Conference, oilfield chemistry, pfp 1, pfp 2, pfp 4, Pipeline Corrosion, Production Chemistry, riser corrosion, steel, strength, Subsurface Corrosion, Svalbard, well integrity
SPE Disciplines:
- Health, Safety, Environment & Sustainability > Safety (0.61)
- Health, Safety, Environment & Sustainability > HSSE & Social Responsibility Management > Contingency planning and emergency response (0.61)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.47)
- (2 more...)
ABSTRACT: Fluid injection into the subsurface may trigger seismic events when shear stress acting on a fracture/fault plane exceeds its shear strength. During injection tests at the CO2 storage pilot at Longyearbyen (LYB), Svalbard, seismic- and non-seismic slipevents were experienced. Two approaches are used to explain the seismic versus non-seismic events occurring at the site. An analytical approach, based on Mohr-Coulomb failure criteria, was employed to evaluate the slip tendency of faults. It shows that vertical faults are more likely to slip at deeper intervals where microseismic events were observed. At shallow injection intervals, where no seismicity was observed, horizontal faults are more likely to slip. The second approach, a velocity stepping direct shear test, showed that the friction coefficient of LYB shale (clay-rich) increases with increasing velocity for bedding parallel faults. This experiment shows that the shale present at shallow interval is prone to velocity-strengthening behavior, which may explain the non-seismic failure during injection tests. 1 INTRODUCTION Capturing carbon dioxide from source points such as power plants and refineries and storing in the subsurface formations is suggested as one of the main measures to mitigate atmospheric greenhouse gases. The Longyearbyen (LYB) CO2 storage pilot is a potential site for CO2 storage on Svalbard, Norway. Longyearbyen is a small city with a population of about 2000 people in the polar wilderness of central Spitzbergen-the main island of the Svalbard archipelago at the northwestern margin of the Barents Sea Shelf (Braathen et al. 2012). The city has a 10 MW coal combusting power plant, which emits about 64,000 tons of CO2 annually (Ogata et al. 2012). The LYB pilot project was initiated by the University Centre on Svalbard (UNIS) to explore feasibility of the site to store the produced CO2 and convert the Longyearbyen to a carbon neutral community. The site is located 5 km east of the Longyearbyen city and eight boreholes (Fig. 1) have been drilled to study properties of the overburden, cap rock and reservoir.
climate change, co 2, coefficient, dh6, direct shear test, fracture, friction coefficient, horizontal stress, in-situ stress, injection pressure, injection test, longyearbyen co 2, normal stress, Norway, norwegian journal, pilot site, Reservoir Characterization, sandstone, shear stress, social responsibility, sustainability, sustainable development, Svalbard, Upstream Oil & Gas
Country:
- Europe > Norway > Svalbard and Jan Mayen > Svalbard > Longyearbyen (1.00)
- Europe > Norway > Norwegian Sea (0.25)
Geophysics: Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (1.00)
Oilfield Places:
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
- Europe > United Kingdom > England > London Basin (0.91)
SPE Disciplines:
Heat Flow and Filtration of Seawater in the Coastal Zone of the Arctic Shelf
Fomin, Y.V.. V. (Moscow Institute of Physics and Technology (State University), Russia) | Zhmur, V.V.. V. (Moscow Institute of Physics and Technology (State University), Russia) | Marchenko, A.V.. V. (The University Center in Svalbard, Norway) | Onishchenko, D.A.. A. (Gazprom VNIIGAZ Ltd, Russia)
Abstract Research sire for the monitoring of heat transfer processes in soils around the pipeline landfall from the shore to sea was organized and equipped in Longyearbyen, Spitsbergen. The data on soil temperature and pore pressure, sea water temperature and tidal variations of the water level are collected for one year of the measurement. Semi-diurnal variations of soil temperature and pore pressure are discovered in all measurement locations. Vertical and horizontal heat fluxes are calculated using the collected data.
air temperature, amplitude, convective heat transfer, heat flux, Longyearbyen, migration, oscillation, Petroleum Engineer, pipeline, pore pressure, Research Site, Reservoir Characterization, soil temperature, spe 166940, thermistor string, tidal variation, tide, Upstream Oil & Gas, variation, water level
SPE Disciplines:
ABSTRACT A field simulation of ice accretion has been performed in the harbour area of Longyearbyen, Spitsbergen, during the winter of 2011. Cylinders with diameters of 10, 20, 40 and 100 mm were exposed to a freezing artificially created periodic spray. This paper presents the density, crystalline structure and salinity of the accreted glaze ice. Hydrostatic weighing was used to measure the ice density, which is a well-established method in fields not related to ice. The method is simple, does not require special equipment and can be accurate to better than 1%. The dependence of the ice properties from the weather conditions is discussed. The experiments demonstrated that the ice salinity was smaller on the larger vertical objects.
accretion, Accretion rate, accuracy, air entrapment, construction, cylinder, equation, experiment, heat flux, heat transfer, ice accretion, ice accretion rate, ice density, ice salinity, production control, production monitoring, reservoir simulation, Reservoir Surveillance, salinity, Scenario, Thickness, tl scenario, Upstream Oil & Gas, variation
SPE Disciplines:
Experimental and Numerical Simulation of CO2 Injection Into Upper-Triassic Sandstones in Svalbard, Norway
Farokhpoor, R.. (NTNU (Norwegian University of Science and Technology)) | Torsæter, O.. (NTNU (Norwegian University of Science and Technology)) | Baghbanbashi, T.. (NTNU (Norwegian University of Science and Technology)) | Mork, A.. (Sintef) | Lindeberg, E.G.B.. G.B. (Sintef)
Abstract Sequestration of carbon dioxide in a saline aquifer is currently being evaluated as a possible way to handle carbon dioxide emitted from a coal-fuelled power plant in Svalbard. The chosen reservoir is a 300 m thick, laterally extensive, shallow marine formation of late Triassic-mid Jurassic age, located below Longyearbyen in Svalbard. The reservoir consists of 300 m of alternating sandstone and shale and is capped by 400 meter shale. Experimental and numerical studies have been performed to evaluate CO2 storage capacity and long term behaviour of the injected CO2 in rock pore space. Laboratory core flooding experiments were conducted during which air was injected into brine saturated cores at standard conditions. Analysis of the results shows that the permeability is generally less than 2 millidarcies and the capillary entry pressure is high. For most samples, no gas flow was detected in the presence of brine, when employing a reasonable pressure gradient. This poses a serious challenge with respect to achieving viable levels of injectivity and injection pressure. A conceptual numerical simulation of CO2 injection into a segment of the planned reservoir was performed using commercial reservoir simulation software and available petrophysical data. The results show that injection using vertical wells yields the same injectivity but more increases in field pressure compare to injection through horizontal wells. In order to keep induced pressure below top-seal fracturation pressure and preventing the fast propagation and migration of CO2 plume, slow injection through several horizontal wells into the lower part of the "high" permeability beds appears to offer the best solution. The high capillary pressure causes slow migration of the CO2 plume, and regional groundwater flow provides fresh brine for CO2 dissolution. In our simulations, half of the CO2 was dissolved in brine and the other half dispersed within a radius of 1000 meter from the wells after 4000 years. Dissolution of CO2 in brine and lateral convective mixing from CO2 saturated brine to surrounding fresh brine are the dominant mechanisms for CO2 storage in this specific site and this guarantees that the CO2 plume will be stationary for thousands of years.
Brine, chemical flooding methods, climate change, co 2, dissolution, enhanced recovery, flow in porous media, Fluid Dynamics, injection, interval 1, kapp toscana group, Longyearbyen, model 1, model 2, Modeling & Simulation, numerical simulation, permeability, Petroleum Engineer, precipitation, relative permeability, Reservoir Characterization, reservoir simulation, saturation, subsurface storage, Svalbard, upper-triassic sandstone, Upstream Oil & Gas
Country:
- North America > United States (0.68)
- Europe > Norway > Svalbard and Jan Mayen > Svalbard > Longyearbyen (0.26)
Geologic Time:
- Phanerozoic > Mesozoic > Jurassic (1.00)
- Phanerozoic > Mesozoic > Triassic > Upper Triassic (0.70)
SPE Disciplines:
Technology:
Save or update focal point
Save a search / focal point to access it again.
Thank you!