Optimal Scheduling for Cyclic Steam Injection Projects

Curry, Guy L.; Chang, Gordon Y.K.; Harper, Ronald G.

doi:10.2523/2627-ms

Cited by 1 publication

(2 citation statements)

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“…Curry et al 16 improved the approach developed by Dunn. 15 They proposed a simple method to optimize the profit from cyclic steam injection and to design the well schedules for steaming on the basis of the availability of the steam generators and the steaming priority of specific wells.…”

Section: Cyclic Steam Injection Processmentioning

confidence: 99%

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Optimization Methodology for Cyclic Steam Injection with Horizontal Wells

et al. 2000

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractHorizontal wells are becoming a very important component in the thermal recovery of heavy oil reservoirs. The success of a cyclic steam injection project depends strongly on the selection of key parameters, such as cycle length and amount of steam injected. The numerical simulation of horizontal wells, especially under non-isothermal conditions, is computationally demanding. When optimization is combined with numerical simulation, the computing time requirement may be prohibitive and it is not guaranteed that the optimal conditions will be found.In this research, a new methodology has been developed for optimizing the cyclic steam injection process for vertical and horizontal wells. The procedure integrates oil production characterization using numerical simulation, net present value maximization through a Quasi-Newton method, and model validation/tuning. The three-stage procedure provides the optimum number and/or duration of cycles, the optimal amounts of steam to be injected in each cycle and the optimal value of the overall economic indicator.The optimization algorithm was successfully validated with published results obtained from the discrete maximum principle. The methodology was then applied to determine the optimal conditions of cyclic steam injection for a horizontal well located in Bachaquero field, Venezuela.

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Section: Cyclic Steam Injection Processmentioning

confidence: 99%

“…13 can be easily modified 19 to represent the cumulative discounted net income without comparing with the cold production, which is given in Eq. 16. In that case, the drilling costs of the well are incorporated at the beginning of the project, and the benefits are calculated without subtracting the primary production.…”

Section: Hyperbolic Declinementioning

confidence: 99%