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Summary In this paper, we present a new approach for simulating reservoirs with tilted fluid contacts produced by hydrodynamics. The proposed method solves a nonlinear inverse problem to determine the aquifer flow field that best reproduces the observed contact tilt. The computational effort required to solve this inverse problem is reduced by choosing a pressure-based objective function and applying gradient-based optimization. This approach is entirely automated, in contrast to previous works that have used laborious trial-and-error methods to estimate the aquifer flow field. In addition, the proposed method introduces no additional physics beyond hydrodynamics to model reservoirs with tilted contacts. The proposed method is integrated into a parallel reservoir simulator. A synthetic reservoir is constructed by introducing an artificial tilt, and the new approach is applied to estimate the aquifer flow field. The estimate produced by the proposed method matches the true flow field well and is able to prevent large fluid motions near the contact surface when simulating production from the reservoir. The proposed method is compared with an existing approach that uses capillary pressure adjustments to hold the tilted contact in place. The proposed method is shown to outperform the existing approach without significantly impacting the simulation results.
Artificial Intelligence, boundary condition, boundary pressure field, capillary pressure, control parameter, equation, flow in porous media, Fluid Dynamics, gradient, interface, inverse problem, machine learning, Modeling & Simulation, objective function, oowc surface, optimization problem, pressure field, reservoir, Reservoir Characterization, reservoir model, reservoir simulation, saturation, seismic surveying, simulator, tilted oowc, Upstream Oil & Gas, variation
Country:
- Europe (1.00)
- Asia > Middle East (1.00)
- North America > Canada (0.93)
- North America > United States > Texas > Dawson County (0.24)
Oilfield Places:
- North America > United States > California > Ventura Basin (0.99)
- Europe > Norway > Norwegian Sea > Møre Basin > PL 442 > Block 6305/8 > Ormen Lange Field > Springar Formation (0.99)
- Europe > Norway > Norwegian Sea > Møre Basin > PL 442 > Block 6305/8 > Ormen Lange Field > Egga Formation (0.99)
- (30 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Technology:
Abstract This paper introduces two new approaches for modeling reservoirs with tilted fluid contacts. We first introduce a method based on local capillary pressure adjustments, which uses adjustments of the capillary pressure near the oil-water contact to ensure that the contact surface does not move during production. The second approach uses hydrodynamic aquifer flow to support the oil-water tilt. A non-linear inverse problem is solved to determine the parameters that control the aquifer flow. Both approaches are implemented in a parallel reservoir simulator and applied to a synthetic reservoir case.
adjustment, Artificial Intelligence, boundary condition, capillary pressure, capillary pressure adjustment, capillary pressure curve, control parameter, equilibrium, flow in porous media, Fluid Dynamics, international petroleum technology conference, objective function, oil-water contact, oowc surface, optimization problem, pressure field, pressure value, Reservoir Characterization, reservoir simulation, tilted oowc, Upstream Oil & Gas, water saturation
Country:
- Europe (0.69)
- Asia > Middle East > Saudi Arabia (0.69)
- North America > United States (0.68)
Oilfield Places:
- Europe > Norway > Norwegian Sea > Møre Basin > PL 442 > Block 6305/8 > Ormen Lange Field > Springar Formation (0.99)
- Europe > Norway > Norwegian Sea > Møre Basin > PL 442 > Block 6305/8 > Ormen Lange Field > Egga Formation (0.99)
- Europe > Norway > Norwegian Sea > Møre Basin > PL 442 > Block 6305/6 > Ormen Lange Field > Springar Formation (0.99)
- (29 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
Technology: Information Technology > Artificial Intelligence > Representation & Reasoning > Optimization (0.47)
Abstract This paper presents and compares the results of the creation of a titled Free Water Level (FWL) from two different modeling methods and the impact on field production. Worldwide there are examples of oil and gas fields with tilted FWL's. These can be generated by different mechanisms. This paper focusses on the modelling of a tilted FWL associated to a hydrodynamic system. There are several methods of modeling a tilted FWL, most of them emphasize on how to create a tilted FWL but lack the correctness of pressure distribution. Two modelling methods were investigated and their results were compared. One is a static method in which a tilted FWL surface is assigned and the respective water saturation (Sw) values are calculated in the model. The second approach is a hydrodynamic method based on the hydrodynamic principle that a tilted FWL is generated by lateral pressure variation related to a water flow below the hydrocarbon bearing interval. Both methods can generate a correct tilted FWL surface and the associated water saturation distribution, but the pressure distribution shows a significant difference depending on which method was applied. The hydrodynamic method delivers a correct pressure distribution in both the hydrocarbon and the water zone as it captures the physical principals of the tilted FWL and aquifer and therefore the corresponding pressure data. In the field-model a realistic stronger pressure support can be observed, leading to realistic recovery figures. The static method provides a correct pressure distribution in the hydrocarbon zone but not in the water zone, and delivers a nonrealistic weaker pressure support, leading to lower production figures. The fundamental difference in pressure distribution has a signiciant impact on a field production and therefore project economics. In conclusion, proper tilted FWL modeling should provide not only a correct FWL surface but also pressure distribution. In cases where a tilted FWL is associated to water flow below the hydrocarbon zone, the hydrodynamic method based on the hydrodynamic principle is recommended.
asset and portfolio management, capillary pressure, different method, FWL, hydrocarbon zone, hydrodynamic method, modeling tilted free water level, modelling, Petroleum Engineer, pressure distribution, reservoir, static method, tilted contact, tilted fwl, tilted fwl surface, Upstream Oil & Gas, water flow, water zone
Country:
- North America > United States (1.00)
- Asia > Middle East (1.00)
- South America (0.68)
- (2 more...)
Oilfield Places:
- South America > Venezuela (0.99)
- South America > Colombia > Caballos Formation (0.99)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin (0.99)
- (97 more...)
SPE Disciplines:
Modelling of a Large Depleted and Tilted Carbonate Oil Rim Reservoir - An Integrated Case Study from UAE
Kundu, Ashish (Abu Dhabi Co For Onshore Petroleum Operations Ltd.) | Voleti, Deepak Kumar (Abu Dhabi Co For Onshore Petroleum Operations Ltd.) | Mokhri, Mohd Nazaruddin (Abu Dhabi Co For Onshore Petroleum Operations Ltd.) | Manseur, Saadi (Abu Dhabi Co For Onshore Petroleum Operations Ltd.)
Abstract When a reservoir undergoes gas cap production without proper pressure maintenance, the underlying oil rim development at a later stage of the field development is very critical and challenging. Adding to the complexity is the tilted Free Water Level. This paper presents a study that was performed to model a large tilted oil rim reservoir that had been massively depleted by the production of the overlaying gas cap. The first part of the paper explains the development history of the oil rim and the low recovery factor that was obtained as a result of the massive gas cap depletion, and the results of previous attempts to revive dead oil wells through artificial means (ESP, booster pumps) which had limited success so far. The second part of the paper elaborates on the study which was carried out to build the concept of a tilted reservoir and later modelled it to get the proper initial water saturation distribution. The variable salinity concept was brought in to validate the proposed tilting scenario. The variable salinity was supported by produced water salinity data. The formation pressure test data also conforms to the tilting concept. The tilting in Free Water level (FWL) was also observed while analyzing capillary pressure data. Model was prepared to map the tilted FWL by krigging FWL depths at individual wells. The challenges that were encountered and overcome during the feasibility study: (1) construction of a new reservoir model incorporating a large set of static and dynamic data showing significant complexity with tilted fluid contacts, variable formation water salinity and initial fluid saturation; (2) multi-scenarios history matching with complex fluid movements and tilted Free Water Level; (3) reservoir uncertainty analysis using learnings from history matching; (4) accurate remaining oil saturation in oil rim. The originality of this study resides in the complex reservoir geology and field production history, in the integrated approach to address requirements of both oil rim and gas cap developments, and in the fact that proposed field revitalization calls for unusual static and dynamic reservoir property modelling which can conceptualize the fluid movement before and after production.
Abu Dhabi, Artificial Intelligence, depletion, Drillstem Testing, drillstem/well testing, free water level, FWL, history matching, information management, injection, injector, log analysis, modelling, oil rim, permeability, producer, reservoir, Reservoir Characterization, reservoir pressure, salinity variation, Scenario, structural geology, tilted carbonate oil rim reservoir, tilted fwl, Upstream Oil & Gas, variation, well logging
Country:
- North America > United States (1.00)
- Asia > Middle East > UAE > Abu Dhabi > Abu Dhabi (0.16)
Oilfield Places:
- South America > Colombia > Putumayo Department > Putumayo Basin > Puerto Colon Field (0.99)
- South America > Colombia > Caballos Formation (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 826 > Mad Dog Field (0.99)
- (57 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Abstract We tackle reservoir simulation model initialization in situations where the current free water level has risen significantly above the original paleo-contact. In such cases, traditional initialization based on primary drainage capillary-gravity equilibrium is insufficient because it does not consider the reimbibition that takes place after primary oil migration. Usage of traditional initialization would require a generation of several thousands of regions to have a satisfactory representation of such phenomenon in the model. We apply this initialization to a reservoir with a complex initial fluid in which hydrocarbons come from multiple sources resulting in significant spatial variation. To capture this spatial variation, the scripting feature of a commercial simulator is used to generate on-the-fly PVT regions and fluid descriptions based on continuous fluid properties. Capillary-gravity equilibrium is then used to initialize the model with the primary drainage capillary pressure curves at the paleo-contact, which gives the minimum water saturation for each grid-block. From this, an imbibition scanning curve is generated for a second initialization based on the current oil-water contact thereby including reimbibition. Our proposed approach was applied to a giant carbonate field for which we were able to generate on-the-fly PVT regions based on continuous property maps of fluid properties such as oil API, solution gas-oil-ratio and water salinity. This resulted in fewer regions being generated and thereby reducing the amount of memory required to initialize the model. We were also able to reduce the initialization time as compared to use of discretized contacts and regions. Our approach enabled us to initialize with both the paleo- and current contacts allowed to continuously vary spatially. This together with the use of a more appropriate capillary pressure hysteresis model, resulted in an initial reservoir state that gave a better match to the saturations obtained from logs. This work illustrates the creation of PVT data and fluid regions on-the-fly based on continuous fluid properties. We also demonstrate the use of continuously varying paleo- and current oil-water contacts without the need to discretize these into regions. These aspects facilitate the propagation of an uncertainty workflow, starting with continuous fluid properties and structural modelling, directly to the simulation model with no need for intermediate discretization and without massive computational penalties.
capillary pressure, capillary pressure curve, carbonate reservoir, complex reservoir, continuous property, current contact, drainage curve, equilibrium region, fluid property, hysteresis model, imbibition curve, initial water saturation, initialization, Killough, Modeling & Simulation, PVT measurement, reservoir simulation, reservoir simulation model, saturation, tilted contact, trapped oil saturation, Upstream Oil & Gas, variation, water saturation
Oilfield Places: Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Abu Dhabi Field (0.97)
SPE Disciplines:
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (0.87)
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