Evaluation of Flooding Strategies for a North Sea Reservoir Using Stochastic Techniques To Model Heterogeneities

Samuelsen, E.T.; Langlais, V.N.; Svanes, Tarald; Dalen, V.; Tyler, K.J.

doi:10.2523/27800-ms

Cited by 3 publications

(4 citation statements)

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“…For offshore heavy oil reservoirs, there are two exploitation methods, cold production and thermal production. Cold heavy oil production mainly used to recover the relatively low viscosity heavy oil (<350cp), and it has been performed in many offshore heavy oil reservoirs, e.g., Bressay field (water flooding, polymer flooding), North Sea Reservoir (water flooding, gas flooding, foam flooding etc), SZ36-1 block, QHD32-6W block and LD10-1 block in Bohai Bay (water flooding, polymer flooding, weak Gel profile control etc) [3][4][5][6][7][8]. For thermal heavy oil production, considering the space resistance of offshore platform, the thermal heavy oil production has limited application.…”

Section: Introductionmentioning

confidence: 99%

Feasibility of the Steam-Assisted-Gravity-Drainage Process in Offshore Heavy Oil Reservoirs with Bottom Water

et al. 2014

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Due to the water-coning problem, cycle steam stimulation (CSS) in the heavy oil reservoirs with bottom water is often less effective, and the oil recovery is even below 10%. Steam assisted gravity drainage (SAGD) is the oil-producing process with a constant pressure-drop (about 0.30 MPa), and it is a potential technique for this reservoirs. Through the implementation of SAGD, bottom water could be effectively controlled. Aiming at the LD heavy oil block in Bohai offshore oilfield, the SAGD performance in heterogeneous heavy oil reservoir with bottom water was numerically studied in this paper. In these simulation models, the water was broken into three components (connate water, injected water and bottom water) to study the water producing in SAGD process. Thus, the influences of startup approach, oillayer thickness, water thickness and the distance between well-pair and bottom-water on the water rising were all simulated. Thereafter, a set of numerical simulations were performed to assess the shale issues in SAGD process, e.g. the vertical and horizontal position of shalebarriers, the shale distribution range, the barrier permeable condition and the macroscopic vertical permeability.Results indicated that bottom water reduced the ultimate recovery of SAGD process by about 10% of the OOIP. The startup by steam-circulation was much suitable for the bottom water heavy oil reservoir instead of CSS approach. The bottom water tremendously reduced the startup pressure-decline rate, and thus the startup-time was prolonged. The distance between well pair and water zone had a great influence on the SAGD performance, and a small distance would delay the beginning time of the steam-chamber rising. For reservoir heterogeneity, the vertical and horizontal heterogeneity have great influence on the drainage process, especially the shale cases. It tremendously decreased the recovery rate by about one time. This investigation could be used as a tool for the successful design of SAGD process in heavy oil reservoirs with bottom water.

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Section: Introductionmentioning

confidence: 99%

Feasibility of the Steam-Assisted-Gravity-Drainage Process in Offshore Heavy Oil Reservoirs with Bottom Water

et al. 2014

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“…Reservoir simulation models, both element models and full field models, have been built for the Brent, Dunlin and Statfjord reservoirs, and are used in the evaluation of drainage strategies 4,5,13 . They are also, to some extent, used for generating long-term production prognoses on a field scale.…”

Section: Optimisation Of the Drilling Programmementioning

confidence: 99%

Optimisation of an Aggressive Drilling Programme at the Statfjord Field - Maximising Production in a Mature Field

Anne-Grethe¹,

Atle²,

Arnesen³

et al. 2002

Proceedings of European Petroleum Conference

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe giant Statoil-operated North Sea oil field Statfjord is currently far down its production decline curve. During 23 years of production more than 60% of the STOOIP has been recovered, and the remaining reserves are characterized by complex distributions of oil, water and gas.In order to obtain a cost-effective production of the remaining oil, an aggressive drilling and intervention programme is necessary. The main challenge that the geoscientists and reservoir engineers face in this scenario is to identify remaining oil in targets becoming increasingly smaller, more complex and more uncertain, and to drain these in the most profitable manner. This paper reviews the working method that has been used at the Statfjord Field when defining a drilling schedule. It shows how the different work processes are linked, starting with the identification of possible new well locations, continuing with the estimation of reserves and risk evaluation and ending up with final drilling projects.

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“…In some North Sea oil reservoirs, produced hydrocarbon gas has been re-injected in water injection wells with the purpose to improve oil recovery and reducing gas export [1][2][3][4][5][6][7][8] . The hydrocarbon gas has been either near miscible [4][5][6] or immiscible WAG [1][2][3]7,8 when contacted with the oil in the reservoir.…”

Section: Introductionmentioning

confidence: 99%

“…The hydrocarbon gas has been either near miscible [4][5][6] or immiscible WAG [1][2][3]7,8 when contacted with the oil in the reservoir. The availability of produced hydrocarbon gas has encouraged use of WAG processes in North Sea oil reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Simulation of the Immiscible WAG Process Using Cycle-Dependent Three-Phase Relative Permeabilities

Larsen

Skauge

1999

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractOil recovery by immiscible WAG is dependent on the saturation cycles that occur in a core-flood or in the reservoir. For the reservoir case, segregation of gas and water can generate other saturation cycles than in a core-flood. In order to predict WAG behavior in the reservoir from experimental results, numerical models with an effective hysteresis description of the three-phase oil, water and gas relative permeabilities should be considered.There has earlier been developed a methodology that accounts for both three-phase flow effects and hysteresis effects in numerical simulations of the immiscible WAG process. Simulation studies have shown how three-phase flow description may influence the choice of drive mechanisms and also the design of a WAG process. Furthermore, a principal component analysis (PCA) is conducted on the simulation model that is consistent with the experimental data. The results from the PCA showed how the hysteresis parameters in the simulation model may be correlated to the physical system. The PCA analysis describe how the three-phase effects in water and gas relative permeabilities are connected to oil recovery.The results show that the cycle-dependent relative permeabilities increase the potential for WAG. Furthermore, the oil production trends with respect to slug length and wateroil ratio is different for models with cycle-dependent hysteresis and without hysteresis.

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Evaluation of Flooding Strategies for a North Sea Reservoir Using Stochastic Techniques To Model Heterogeneities

Cited by 3 publications

References 0 publications

Feasibility of the Steam-Assisted-Gravity-Drainage Process in Offshore Heavy Oil Reservoirs with Bottom Water

Feasibility of the Steam-Assisted-Gravity-Drainage Process in Offshore Heavy Oil Reservoirs with Bottom Water

Optimisation of an Aggressive Drilling Programme at the Statfjord Field - Maximising Production in a Mature Field

Simulation of the Immiscible WAG Process Using Cycle-Dependent Three-Phase Relative Permeabilities

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