Advanced ICD Application Alleviating Well Intervention Challenges

Awad, Mohamed Omar; Ajmi, Moudi F. Al; Safar, Ahmad; Rajagopalan, V S

doi:10.2118/175204-ms

Cited by 6 publications

(2 citation statements)

References 2 publications

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“…The steady state simulator works to enhance the design of the completion and the selection of the downhole devices. Hence, since it is a static simulator, the wellbore hydraulics simulation is done at a single time step (Carvajal et al, 2013;Awad et al, 2015).…”

Section: Wellbore Simulationmentioning

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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Section: Wellbore Simulationmentioning

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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“…effectively in order to improve production and net present value (NPV), otherwise the ICDs even would be overlooked. Awad et al (2015) showed a typical flow diagram that should be used in a proper modeling and designing of ICD. This is presented in Figure 3.…”

Section: Introductionmentioning

confidence: 99%

Optimizing oil recovery using new inflow-control devices (ICDs) skin equation

Uche¹,

Obah²,

Onwukwe³

et al. 2019

J. Petroleum Gas Eng.

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Inflow-control devices (ICDs) were developed to avoid coning problems in long horizontal wells mainly in heterogenous formations, but cause some additional drawdown which does not contribute to rate increase. This rate reduction is seen to be impairment to the productivity of horizontal wells. Therefore, horizontal wells that are equipped with ICDs require a pre-quantification of their productivity by determining skin caused by each ICD nozzle size. This will help prevent additional expenditure that will be spent for a corrective horizontal well intervention. Many authors have proposed equations that can be used to estimate skin due to damage, partial completion, slanted well and perforation. No author has provided a skin equation that can be used to estimate recoverable and productivity loss that may result from the use of inflow control devices. In this work, a 3D numerical model which includes inflow control devices along horizontal wells was used to investigate reservoir and production performances of various ICD nozzle sizes. Different productivity losses from different nozzle sizes were seen as skin and a 0.002ft 2 ICD nozzle flow area estimated to have a zero skin. Consequently, a simple equation for calculating this skin due to restricted fluid entry through ICD nozzles was derived. The derived equation which shows insignificant deviation from skin equation is then used for selecting the right nozzle size for production and recovery optimization from horizontal wells.

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Reducing Well Costs and Extending Field Life with Intelligently Controlled Trilateral and Quadrilateral TAML Level-5 Multilaterals

Glaser

Butler

Liland

2017

SPE/IADC Drilling Conference and Exhibition

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Since 1996, more than 260 multilateral junctions have been installed in Norwegian Continental Shelf (NCS) fields; currently, 25 laterals are completed annually. This paper discusses a TAML Level-5 multi-branch multilateral system that was installed in Troll field in 2012. It is now the predominant system, with more than 200 junctions installed in subsea wells. This latest generation of sealed multilateral junctions combined with flow control equipment, including surface-controlled interval control valves (ICVs) and autonomous inflow control devices (AICDs), enables full production control of the main bore and each lateral. The production life of multilateral wells of the Norwegian Troll field is limited by gas breakthrough and/or water cut. Historically, this issue was mitigated by using intelligent completions to control the flow of a maximum of two laterals. If a breakthrough occurred in a lower lateral on wells with three or more laterals, all laterals would have to be choked or shut-in together. This process resulted in lost production and reduced recovery from the other laterals. As trilaterals and quadrilaterals became more common, however, it became necessary to provide flow control for all branches. In October 2012, the Troll team installed the first multibranch multilateral system on Troll N-24. This system is believed to have been the first TAML Level-5, three-branched well with individual branch control installed worldwide. With this new and innovative junction and completion system, the operator could optimize the oil production from new and extended-reach multilateral wells. In addition, the implementation of multilateral technology (MLT) early during the planning stage enables the addition of production intervals at a cost of 20% or less of the initial well cost, which makes many marginal field developments viable projects. Multilateral junctions are typically constructed from the bottom up; the lower main bore is drilled, completed, and prepared for production before milling the window for junctions above. To help mitigate the risk with these operations, several technologies have been implemented, including premilled windows, extended length whipstocks, and lateral screen deployment. On multilateral operations, a dedicated coordinator focus and a proactive engineering team has helped eliminate and/or reduce installation risk to an acceptable level for operators using the technology. Presently, this innovative multilateral solution helps increase oil recovery from Troll and other fields. This increase should help expand the functionality and economic viability of MLT worldwide, particularly in thin reservoirs.

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Advanced ICD Application Alleviating Well Intervention Challenges

Cited by 6 publications

References 2 publications

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

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

Optimizing oil recovery using new inflow-control devices (ICDs) skin equation

Reducing Well Costs and Extending Field Life with Intelligently Controlled Trilateral and Quadrilateral TAML Level-5 Multilaterals

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