The First Passive Inflow Control Device That Maximizes Productivity During Every Phase of a Well's Life

García, Luis Antonio Ribot; Coronado, Martin P.; Russell, Ronnie; Garcia, Gonzalo Alberto; Peterson, Elmer Richard

doi:10.2523/iptc-13863-ms

Cited by 23 publications

(9 citation statements)

References 6 publications

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“…In 2009, Garcia et al published a pressure drop correlation as a function of the pressure drop coefficient, mixture density, and mixture flow velocity, one of the first attempts to provide a performance function that could be incorporated into a reservoir simulator (Garcia et al, 2009). Peterson et al (2010) built upon this work to demonstrate that an ICD pressure drop coefficient correlates strongly to Reynolds number, allowing reservoir simulators to better determine ICD performance for multiphase/multicomponent mixtures.…”

Section: Performance Description: Restriction-style Icd Designsmentioning

confidence: 99%

“…For production of bitumen emulsion, pressure drop within the frictional ICD is determined after calculating a friction factor (Garcia, 2009). Assuming that the liquid phase behaves as a power law fluid, the friction factor for both laminar and turbulent behavior can be captured in the equations established by (Darby et al (1992).…”

Section: Performance Description: Frictional-style Icdsmentioning

confidence: 99%

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Management of Steam Flashing in SAGD Completion Design via the Implementation of Flow Control Devices

Banerjee

Hasçakir

2015

Day 3 Wed, November 25, 2015

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The integrity of Steam-Assisted Gravity Drainage (SAGD) wells are often threatened by the very steam that provides the process its name. High rate steam production, or the adiabatic flashing of steam condensate to a vapor state, often creates an environment of Љflashing erosionЉ, erosive damage created by the water-cutting effect of high velocity wet steam or the corrosive elements (e.g., carbonic acid) that can be associated with low temperature condensate. Condensate flashing to steam also carries additional risk from Љcavitation erosionЉ, erosion of completion equipment that occurs from the sudden shock wave impacts caused by the implosion of small liquid-free zones with the condensate, similar to the wellunderstood water hammer effect. Conventionally, to prevent the production of live steam or the flashing of steam condensate, operators have relied upon choking production rates based upon monitored temperature differences between injected and produced fluids. However, this methodology based on subcool carries its own risks and undermines the economic viability of SAGD projects. Another approach is to improve conformance of steam injection and fluid production by installing inflow/injection control devices (ICDs) in either, or both, the SAGD injector and producer. If properly designed, these devices in the producer can equalize heel-to-toe influx of bitumen emulsion, provide greater control of the sub-cool, and behave as an autonomous (or self-regulating) valve. This presentation will focus upon this last design objective. By coupling published performance equations for various ICD designs with steam behavior equations, competing designs will be evaluated for their likelihood of steam flashing within a SAGD completion and their respective ability to control flashed steam prior to the steam creating damage in the completion. Further, the discussion will examine possible future avenues of research, such as ICD designs with a steam throttle effect driven through a velocity-sensitive choking of steam production.

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Section: Performance Description: Restriction-style Icd Designsmentioning

confidence: 99%

Section: Performance Description: Frictional-style Icdsmentioning

confidence: 99%

Management of Steam Flashing in SAGD Completion Design via the Implementation of Flow Control Devices

Banerjee

Hasçakir

2015

Day 3 Wed, November 25, 2015

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“…Therefore, the risk of non-uniform water injection and early water breakthrough in the adjacent production wells should be expected (Garcia et al, 2009).…”

Section: Introductionmentioning

confidence: 99%

“…Profound understanding of the reservoir topology, its geological setting and connectivity of various compartments, and the dynamic interactions between wells are critical for setting optimal field development plans and production strategies. Therefore, decisions concerning production and injection rates, well placement, and completion design are all affected by the outcomes of dynamic reservoir simulations during its lifespan (Garcia et al, 2009).…”

Section: Introductionmentioning

confidence: 99%

Downhole flow controllers in mitigating challenges of long reach horizontal wells: A practical outlook with case studies

Chammout¹,

Ghosh²,

Alklih³

2017

J. Petroleum Gas Eng.

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Production and injection in long reach horizontal wells pose several challenges in production optimization, flow assurance and reservoir management. Horizontal wells are known to be superior to vertical wells in terms of productivity, however, they are also susceptible to early water and/or gas cut production due to the heel-toe effect and/or permeability contrasts. Uniform distribution of water injection into all zones can also be a challenge in case of high-permeability streaks and fractures. To negate some of the adverse reservoir properties and to control the flow profile of production and injection fluids, downhole flow control devices are increasingly in use and beneficial in regulating flow, improved overall reservoir sweep, improved productivity from the tail section of the well and reduced water coning or gas cusping. Wellbore hydraulics for a long reach well completed with downhole valves have great influence on the reservoir performance and recovery in the long run. This paper presents a discussion aimed at better understanding of the critical challenges that long reach horizontal wells are prone to in terms of completion, as well as the developments so-far that have been applied to capture the physics across the long horizontal section. Three case studies are also discussed with some details emphasizing practical experiences of such wells.

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“…Since a typical well with ICDs usually in production from 5 to more than 20 years, the longterm reliability of such a device is crucial to the well's overall success. Thereby an ICD must have certain performance features during each phase of a well's life to minimize or eliminate the undesirable results 1 . At the beginning of drilling and production process, the ICD must have a high plugging resistance for drilling and completion fluid.…”

Section: Introductionmentioning

confidence: 99%

Selection and Optimization Study on Passive Inflow Control Devices by Numerical Simulation

Zeng

Wang

Yang

et al. 2013

Day 2 Tue, October 29, 2013

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In long horizontal wells, production rate is typically higher at the heel than that at the toe. The resulting imbalanced production profile may cause early water or gas breakthrough into the wellbore. Once coning occurs, well production may be severely decreased due to limited flow contribution from the toe. To eliminate this imbalance, inflow control devices (ICDs) are placed in each screen joint to balance the production inflow profile across the entire lateral length and to compensate for permeability variations. Currently, there are three different passive ICD designs in the industry: nozzle-based, helical channel, and tube-type. They use restriction mechanism (nozzle-based), friction mechanism (helical channel) or cooperating the two (tube-type) to achieve a uniform inflow profile. However, the reality is that none of these ICDs alone meets the ideal requirements of an ICD designed for the life of the well: high resistance to both plugging and erosion, high viscosity insensitivity, and high density sensitivity. Therefore, the selection and optimization of ICDs for a specific reservoir requires for further study. In this paper, three computational fluid dynamic based, numerical models of these ICDs with same flow resistance rating (FRR) were developed to characterize the flow performance. The results show that the throttle pressure drop depends on fluid properties, and geometries of each ICD. The weight of each factor that affects pressure drop was determined by maximizing deviations combining with analytic hierarchy process, and subsequently optimal ICD under specific reservoir condition was selected with the help of fuzzy comprehensive evaluation, thereby an ICD selection diagram was built. For a specific reservoir, we will have the selected ICD with best pressure drop composition by optimizing its structural parameter, which has best corrosion resistance and least viscosity sensitivity.

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The First Passive Inflow Control Device That Maximizes Productivity During Every Phase of a Well's Life

Cited by 23 publications

References 6 publications

Management of Steam Flashing in SAGD Completion Design via the Implementation of Flow Control Devices

Management of Steam Flashing in SAGD Completion Design via the Implementation of Flow Control Devices

Downhole flow controllers in mitigating challenges of long reach horizontal wells: A practical outlook with case studies

Selection and Optimization Study on Passive Inflow Control Devices by Numerical Simulation

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