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Northern North Sea
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 043 > Block 30/7 > Martin Linge Field > Tarbert Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 043 > Block 30/7 > Martin Linge Field > Ness Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 043 > Block 30/7 > Martin Linge Field > Lunde Formation (0.99)
- (29 more...)
- Well Drilling (1.00)
- Well Completion > Sand Control > Gravel pack design & evaluation (1.00)
The Nova field is in the northeastern North Sea. Reservoir sands are at depths of 2500–2800 m, with a pressure of approximately 290 bar and temperatures up to 110 C. The field will be operated with six wells--three oil producers and three water injectors--with an injector/producer pair in each of the main fault compartments.
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 418 > Block 35/9 > Nova Field > Viking Formation > Heather Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 418 > Block 35/9 > Nova Field > Rannoch Formation > Heather Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 418 > Block 35/8 > Nova Field > Viking Formation > Heather Formation (0.99)
- (3 more...)
ABSTRACT We describe, implement, and show the results of a localized ensemble-based approach for seismic amplitude-variation-with-offset (AVO) inversion with uncertainty quantification. Ensembles are simulated from prior probability distributions for fluid saturations and clay content. Starting with continuous saturations and clay content variables, we use depth-varying models for cementation and grain contact theory, Gassmann fluid substitution with mixed saturations, and approximations to the Zoeppritz equations for the AVO attributes at the top-reservoir. The local conditioning to seismic AVO observations relies on (1) the misfit between ensemble simulated seismic AVO data and the field observations in a local partition of the grid/local patch, of inlines/crosslines around the locations where we aim to predict, (2) correlations between the simulated reservoir properties and the data in local patches, and (3) local assessment to avoid unrealistic updates based on spurious correlations in the ensembles. Data from the Alvheim field in the North Sea are used to demonstrate the approach. The influence of the prior information from the well logs in combination with the seismic reflection data indicates the presence of higher oil and gas saturation in the lobe structures of the field and increased clay content at their edges.
- Geology > Mineral > Silicate > Phyllosilicate (0.93)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.93)
- Geology > Geological Subdiscipline > Geomechanics (0.84)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > Våle Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > A2 North Heimdal T60 Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Hermod Formation > Våle Formation (0.99)
- (25 more...)
Ocean services provider DeepOcean and Aker BP have successfully completed subsea trials with an autonomous inspection drone (AID) at the Aker BP-operated Alvheim field in the central North Sea. "While testing of autonomous technology is exciting on its own, our primary purpose was to find out if subsea inspection can be conducted more cost-efficiently and with better and more precise data quality with this new technology and associated methods," said Jarle Marius Solland, operations manager at Aker BP. "The conclusion is definitely yes." The AID project is a strategic partnership between DeepOcean, Argus Remote systems, and Vaarst, where a system has been developed with industry guidance, support, and funding from Aker BP to bring a platform to market. "The first inspection trial was highly encouraging. Based on this, we believe we can inspect the specific subsea infrastructure at Alvheim noticeably faster next year," said Kristoffer Johansen, technology manager at DeepOcean.
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > Våle Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > A2 North Heimdal T60 Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Hermod Formation > Våle Formation (0.99)
- (21 more...)
The Impact of Autonomous Inflow Control Valve on Improved Oil Recovery in a Thin-Oil-Rim Reservoir
Taghavi, Soheila (University of South-Eastern Norway / InflowControl AS (Corresponding author)) | Aakre, Haavard (InflowControl AS) | Tahami, Seyed Amin (University of South-Eastern Norway) | Moldestad, Britt M. E. (University of South-Eastern Norway)
Summary Oil production from thin-oil-rim fields can be challenging as such fields are prone to gas coning. Excessive gas production from these fields results in poor production and recovery. Hence, these resources require advanced recovery methods to improve the oil recovery. One of the recovery methods that is widely used today is advanced inflow control technology such as autonomous inflow control valve (AICV). AICV restricts the inflow of gas in the zones where breakthrough occurs and may consequently improve the recovery from thin-oil-rim fields. This paper presents a performance analysis of AICVs, passive inflow control devices (ICDs), and sand screens based on the results from experiments and simulations. Single- and multiphase-flow experiments are performed with light oil, gas, and water at typical Troll field reservoir conditions (RCs). The obtained data from the experiments are the differential pressure across the device vs. the volume flow rate for the different phases. The results from the experiments confirm the significantly better ability of the AICV to restrict the production of gas, especially at higher gas volume fractions (GVFs). Near-well oil production from a thin-oil-rim field considering sand screens, AICV, and ICD completion is modeled. In this study, the simulation model is developed using the CMG simulator/STARS module. Completion of the well with AICVs reduces the cumulative gas production by 22.5% and 26.7% compared with ICDs and sand screens, respectively. The results also show that AICVs increase the cumulative oil production by 48.7% compared with using ICDs and sand screens. The simulation results confirm that the well completed with AICVs produces at a beneficial gas/oil ratio (GOR) for a longer time compared with the cases with ICDs and sand screens. The novelty of this work is the multiphase experiments of a new AICV and the implementation of the data in the simulator. A workflow for the simulation of AICV/ICD is proposed. The simulated results, which are based on the proposed workflow, agree with the experimental AICV performance results. As it is demonstrated in this work, deploying AICV in the most challenging light oil reservoirs with high GOR can be beneficial with respect to increased production and recovery.
- Asia (1.00)
- North America > United States > Wyoming > Carbon County (0.65)
- Europe > Norway > North Sea > Northern North Sea (0.49)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- South America > Colombia > Putumayo Department > Putumayo Basin > Acordionero Field (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > Våle Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > A2 North Heimdal T60 Formation (0.99)
- (36 more...)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Flow control equipment (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Available data includes unprocessed field data in SEG Y format, two well logs, and one very basic Seismic Unix script. "Comparison of Seismic Inversion Methods on a Single Real Data Set" by Robert G. Keys and Douglas J. Foster says: "Since the workshop data set is in the public domain, readers can apply their own methods to the data." More information is available in Robert G. Keys and Douglas J. Foster's "Comparison of Seismic Inversion Methods on a Single Real Data Set", available within SEG eBooks. Also in Gislain B. Madiba and George A. McMechan, 2003, "Processing, inversion, and interpretation of a 2D seismic data set from the North Viking Graben, North Sea"
- Europe > United Kingdom > North Sea > Northern North Sea (1.00)
- Europe > Norway > North Sea > Northern North Sea (1.00)
- Europe > United Kingdom > North Sea > Central North Sea (0.76)
- Europe > Norway > North Sea > Central North Sea (0.76)
- Geology > Structural Geology > Tectonics > Extensional Tectonics (0.76)
- Geology > Structural Geology > Fault > Dip-Slip Fault > Normal Fault (0.76)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Calgary-based Suncor Energy said the Terra Nova floating production, storage, and offloading (FPSO) vessel has safely restarted production and is expected to ramp up in the coming months. The restart comes after the completion of the Terra Nova Asset Life Extension project, with the FPSO undergoing extensive repairs in a port in northwestern Spain with the goal of extending the vessel's operational life through 2031. At more than 290 m long--about the size of three football fields laid end-to-end--and 45 m wide, the FPSO can hold 960,000 bbl of oil and accommodate up to 120 people while producing, according to Suncor. "Focusing on safety and operational integrity, we have brought this key offshore project online, providing additional cash flow for our shareholders and many benefits to the Newfoundland and Labrador and Canadian economies," said Suncor President and CEO Rich Kruger. "We appreciate the collaboration and support from the provincial and federal governments regarding this project."
- North America > Canada > Newfoundland and Labrador > Newfoundland > North Atlantic Ocean (0.53)
- Europe > Norway > North Sea > Northern North Sea (0.53)
- North America > Canada > Newfoundland and Labrador > Labrador (0.34)
- North America > Canada > Alberta > Census Division No. 6 > Calgary Metropolitan Region > Calgary (0.27)
We describe, implement and show results of a localized ensemble-based approach for seismic AVO inversion with uncertainty quantification. Ensembles are simulated from continuous prior probability distributions for fluid saturations and clay content. Starting with continuous saturations and clay content variables, we use depth-varying models for cementation and grain contact theory, Gassmann fluid substitution with mixed saturations, and approximations to the Zoeppritz equations for the AVO attributes at the top-reservoir. The local conditioning to seismic AVO observations relies on i) the misfit between ensemble simulated seismic AVO data and the field observations in a local partition of the grid - local patch, of inlines/crosslines around the locations where we aim to predict, ii) correlations between the simulated reservoir properties and the data in local patches, iii) local assessment to avoid unrealistic updates based on spurious correlations in the ensembles. Data from the Alvheim field in the North Sea are used to demonstrate the approach. The influence of the prior information from the well logs in combination with the seismic reflection data indicates presence of higher oil and gas saturation in the lobe structures of the field and increased clay content at their edges.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (1.00)
- Geology > Mineral > Silicate > Phyllosilicate (0.92)
- Geology > Geological Subdiscipline > Geomechanics (0.83)
- Geology > Sedimentary Geology (0.67)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > Våle Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > A2 North Heimdal T60 Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Hermod Formation > Våle Formation (0.99)
- (24 more...)
Summary Many horizontal oil wells will after a time start producing unwanted fluids. Autonomous inflow control valves may help to choke these unwanted fluids and consequently improve carbon efficiency. This paper publishes new experimental data describing how an autonomous inflow control valve manages medium-light oil (6 cp), water, and gas at reservoir conditions. A further objective is to evaluate how this valve might impact well performance under various conditions. To verify the single- and multiphase flow behavior of the valve, extensive flow loop experiments were performed. Initial testing was done in a model fluid laboratory, while a more extensive test was performed at reservoir conditions (i.e., with formation water, reservoir oil, and hydrocarbon gas at the given reservoir temperature and pressure). To explore and understand the impact of this valve for various reservoir scenarios, a simple conceptual reservoir model with realistic boundary conditions was used. At various differential pressures, the single-phase oil, water, and gas rates were measured. Performance at varying water and gas fractions was measured to get an improved understanding and knowledge of multiphase flow occurring in a well. The results show clearly that the valve will choke gas and water effectively, both at single-phase and multiphase flow conditions. The reservoir and model fluid evaluations show consistent results. The valve shows roughly a monotonic decreasing total rate with decreasing oil fraction, implying that the valve will always prioritize sections with the largest oil fraction. A mathematical model match of the valve performance is possible via the 10-parameter extended autonomous inflow control device (AICD) equation that enables practical evaluation of the valve in industry-standard reservoir simulators. Various scenarios are explored with a conceptual reservoir model, and the autonomous inflow control valve shows its capacity to reduce water production and enable a more gradual and controlled increase in gas/oil ratio for most scenarios. The autonomous inflow control valve shows its largest potential to reduce unwanted fluids and increase oil recovery when used in segmented reservoirs. In cases with uncertain aquifer and/or gas cap strength, or large variation in effective permeability, the valve will make an infill well more robust as it autonomously adapts to reality, chokes unwanted fluids, and consequently enables more carbon-efficient reservoir management.
- North America > United States (1.00)
- Asia > Middle East (0.94)
- Europe > Norway > North Sea > Northern North Sea (0.28)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > Våle Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > A2 North Heimdal T60 Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Hermod Formation > Våle Formation (0.99)
- (37 more...)
Reservoir Drilling and Openhole Gravel Packing with High-Density Cesium Formate Fluids in a High-Pressure, Marginal Mud Window Environment at Martin Linge
Nilsen, Simen Jøsang (Equinor ASA) | Obrestad, Hanne Undheim (Equinor ASA) | Kaarigstad, Håvard (Equinor ASA) | Mansurova, Nadia (Equinor ASA) | Solvoll, Tom Are (Equinor ASA) | Løchen, Johan (Sinomine Specialty Fluids) | Howard, Siv (Sinomine Specialty Fluids (Corresponding author)) | Abrahams, Ben (Sinomine Specialty Fluids) | Busengdal, Christian (Sinomine Specialty Fluids)
Summary High-density cesium/potassium (Cs/K) formate fluids were successfully utilized from reservoir drilling to upper completion installation in five productive Martin Linge high-rate gas wells. Four wells were completed with openhole gravel pack (OHGP) and one with standalone sand screens. The gravel packing operation marks what is considered to be the highest density carrier fluid OHGP successfully completed worldwide, with a specific gravity (SG) of 2.06. A complex operation under pressure and temperature conditions (745–780 bar and 135–140°C) that almost qualify as high pressure/high temperature (HP/HT), including managed pressure drilling (MPD), overbalanced screen running, and openhole gravel packing, was simplified by using the same base brine throughout the operation. Cs/K formate reservoir drilling fluid (RDF) and screen-running fluid were designed with biopolymeric additives and minimal calcium carbonate bridging particles. Clear Cs/K formate brine was chosen as gravel pack (GP) carrier fluid. The use of Cs/K formate fluids for all stages of the operation reduced the complexity of transitioning between the operational stages. In addition, the reservoir was only exposed to one filtrate without application of damaging weighting solids. The drilling fluid contributed to successful MPD and delivered wells with very good hole quality in the reservoir, which consisted of interbedded sandstone, coal stringers, and shale. The shale-stabilizing properties of concentrated formate brine–based fluids provided acceptable conditions for extended openhole time and allowed additional logging runs, including pore pressure measurements, under near-HP/HT conditions, before running the screens. One bottom-up cleanout was conducted before the screen-running fluid was circulated in and the screens installed. The spurt and seepage losses were low throughout the drilling and screen-running phases. No breaker treatment was required in any of the wells. All wells have proved to have good initial productivity and high well productivity index. The successful OHGP operations performed with the high fluid densities required in Equinor’s Martin Linge field have set a new standard for well completions in challenging high-pressure environments.
- Asia (1.00)
- North America > United States > Texas (0.94)
- Europe > Norway > North Sea > Northern North Sea (0.66)
- Geology > Geological Subdiscipline (0.67)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.47)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.34)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 043 > Block 30/7 > Martin Linge Field > Tarbert Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 043 > Block 30/7 > Martin Linge Field > Ness Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 043 > Block 30/7 > Martin Linge Field > Lunde Formation (0.99)
- (64 more...)
- Information Technology > Communications > Networks > Sensor Networks (0.46)
- Information Technology > Software > Programming Languages (0.40)
- Information Technology > Artificial Intelligence (0.37)