Dynamic SAGD Well Flow Control Simulation

Stone, Terry; Yardumian, Hrant E.; Bailey, William J.; Damas, Carlos; Naccache, P.F.; Morton, Alison

doi:10.2118/138054-ms

Cited by 14 publications

(3 citation statements)

References 3 publications

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“…Other recent work examining SAGD operations with wells incorporating inflow-control devices (ICDs) and flow-control valves under feedback control, looped multisegmented-well (MSW) topology, and pressure/rate control at several points internal to the wellbore was discussed by Stone et al (2010aStone et al ( , 2010b.…”

Section: Reviewmentioning

confidence: 99%

Practical Control of SAGD Wells With Dual-Tubing Strings

Stone

Brown

Güyagüler

et al. 2014

Journal of Canadian Petroleum Technology

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Claims include (i) providing a pair of horizontal wells, separated by a distance of approximately 3 to 8 m, each with a liner and an additional tubing string extending through the full length of the liner, (ii) conductive heating of the interwell region by circulating steam in both wells for an initial period of time, (iii) subsequent injection of steam in the upper well through both the long tubing string and at the heel of the annulus at a constant pressure that is less than fracture pressure, and (iv) simultaneously, producing subcooled fluids in the lower well, where the subcool is maintained by controlling the production rate so that the fluid state remains somewhat below saturated steam conditions, thereby enforcing a column of steam-free liquid just above the lower producer.

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Section: Reviewmentioning

confidence: 99%

Practical Control of SAGD Wells With Dual-Tubing Strings

Stone

Brown

Güyagüler

et al. 2014

Journal of Canadian Petroleum Technology

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“…Recently, several researchers have used proportional‐integral‐derivative (PID) control for automatic feedback control of the SAGD variables to maintain the interwell subcool temperature. Stone et al studied the PID control strategy to continuously control the valve apertures in 3D models with a single SAGD well pair. Both injector and producer wells were divided into four intervals and the flow rate was controlled in each segment using separate flow control valves.…”

Section: Introductionmentioning

confidence: 99%

Real‐time feedback control of SAGD wells using model predictive control to optimize steam chamber development under uncertainty

et al. 2018

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The efficiency of steam assisted gravity drainage (SAGD) operation depends on developing a uniform steam chamber by maintaining an optimal subcool temperature along the length of the well pair. Implementing operational parameters obtained from model‐based optimization directly in the field may not lead to the desired subcool temperature. Based on the real‐time measurements from surface and downhole sensors, along with other well and surface constraint information, a real‐time feedback control of SAGD well pairs can be implemented to optimize subcool and steam chamber development. Model predictive control (MPC), which is a multivariable constrained controller, provides a framework for such control. To evaluate the use of MPC for real‐time control of SAGD wells, a case study is performed using a 3D heterogeneous reservoir model. Porosity and permeability realizations are created and ranked based on net present value (NPV). One of the realizations is considered as the ‘true’ reservoir, and two other realizations are selected to represent different cases of uncertain reservoir models. For each model, a reservoir simulator is used to find the optimum rates and subcool temperature, which become the set‐points for MPC to operate the wells. We compare the steam chamber growth and NPV calculated using MPC with the base case where no MPC is used and discuss the implementation advantages. Since MPC led to expedited and accurate tracking of optimized operating targets obtained using reservoir models, ∼18 % improvement in NPV is achieved compared to manual open‐loop application of optimum rates, a practice used commonly in the field.

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“…Sustaining this performance for high viscosity bitumen reservoirs with horizontal wells is extremely difficult and sophisticated techniques may be necessary. For example, Stone et al (2010) investigated the use of flow control valves to control steam placement in the early stages of a SAGD injection process including the initial steam circulation period. To improve the uniformity of steam distribution and the efficiency of oil production, multiple tubing strings are now being used by various operators, especially in Canada.…”

Section: Introductionmentioning

confidence: 99%

Modeling Multi-tubing Wells in Reservoir Simulation

Browning

Morton

2011

All Days

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This paper describes the modeling of single and dual tubing wells in a full-field reservoir simulator. The tubings associated with each well are modeled in terms of one primary and one or more secondary wells. The multi-segment well modeling techniques incorporated in the simulator have been extended to model multi-tubing systems thereby avoiding the requirement to model special grid blocks representing a wellbore. Wells with two or more tubings present a significant challenge to reservoir simulation where traditionally the coupling of the well with the reservoir, however complex, is solved in terms of a single surface inlet or outlet.The case studies have been selected to demonstrate that injectors and producers can both be modeled in terms of primary and secondary wells both with targets and constraints. Comparisons are presented showing the differences between single and dual tubing injection and production schemes. An example of a multi-tubing production schemes is also included. These demonstrate that modeling wells with two or more tubings using the multi-segment well approach is practicable for the simulation of hydrocarbon recovery processes.

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Dynamic SAGD Well Flow Control Simulation

Cited by 14 publications

References 3 publications

Practical Control of SAGD Wells With Dual-Tubing Strings

Practical Control of SAGD Wells With Dual-Tubing Strings

Real‐time feedback control of SAGD wells using model predictive control to optimize steam chamber development under uncertainty

Modeling Multi-tubing Wells in Reservoir Simulation

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