Comprehensive ICD/ICV Completion Design Workflow Practiced in Green Oilfield Offshore, Abu Dhabi

Javid, Khalid; Mustafa, Hammad; Chitre, Sunil; Anurag, A; Sayed, Mohamed; Kuliyev, Myrat; Ibrahim, Khalil; Saeed, Yawar

doi:10.2118/189400-ms

Cited by 4 publications

(2 citation statements)

References 22 publications

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“…Fluid flows from the oil reservoir into the wellbore through these completions, which result in additional pressure drop affects the production rate of horizontal wells. However, prediction models for horizontal well production rate based on slotted screen and ICD completions have been simplified, such that only the flow in the center tubing is considered while the flow in the annulus is disregarded (Alvarez, A. C. , et al, 2014;Javid, K. , 2018;Droppert, V. , 2020;Gurses, S. F., 2013;Goh, G. , 2016;Bol, L. , 2016;Shahkarami, A. , 2020;Eltazy, E., 2019;D Li, 2017). They all carried out the research on related models for ICD completion, but did not consider the effects of annulus flow.…”

Section: Introductionmentioning

confidence: 99%

Flow simulation for a horizontal well with slotted screen and ICD completions based on the wellbore–annulus–reservoir model

Luo

Liao²,

Wang³

et al. 2021

JER is an international, peer-reviewed journal that publishes f

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A flow is observed in the pipe for the horizontal section of slotted screen completion and inflow control device (ICD) completion, and an annulus flow exists between the pipe and the borehole wall. Based on the principles of mass conservation and momentum conservation, a model for variable mass flow in an oil reservoir to simulate wellbore–annulus–reservoir state in the horizontal section of slotted screen completion and ICD completion is proposed. Consequently, based on the newly established formation transient seepage model and wellbore and annulus variable mass flow model, an accurate prediction of the production rate of a horizontal well as well as optimized design parameters for slotted screen completion and inflow control device (ICD) completion are achieved. The predicted flow profiles of the established model are confirmed using the simulation software from Computer Modeling Group Ltd. When external casing packers are not considered, findings show that the predicted production rates of both slotted screen completion and ICD completion, which are obtained using the variable mass flow models without annulus flow modeling, are higher than the rates obtained using the variable mass flow models with annulus flow modeling. Both models show that the pressure profile and flow profile of the borehole wall are more uniform in wellbore–annulus–reservoir in horizontal wells. The flow model for horizontal wells with annulus flow modeling should be established to improve the accuracy of the predicted production.

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Section: Introductionmentioning

confidence: 99%

Flow simulation for a horizontal well with slotted screen and ICD completions based on the wellbore–annulus–reservoir model

Luo

Liao²,

Wang³

et al. 2021

JER is an international, peer-reviewed journal that publishes f

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show abstract

“…In recent years both ICDs and ICVs have gained popularity and are being applied to a wide range of fields. Their efficiency has been studied through a variety of field cases (see, e.g., Al-Enezi et al, 2012;Al-Khelaiwi and Davies 2007;Al-Thuwaini et al, 2009;Broni-Bediako et al, 2019;Das and Al-Enezi, 2014;Dimitios et al, 2009;Gurses et al, 2019;Javid et al, 2018;Raffn et al, 2007).…”

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confidence: 99%

A semi-implicit approach for the modeling of wells with inflow control completions

Flauraud

Ding

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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In the last two decades, new technologies have been introduced to equip wells with intelligent completions such as Inflow Control Device (ICD) or Inflow Control Valve (ICV) in order to optimize the oil recovery by reducing the undesirable production of gas and water. To optimally define the locations of the packers and the characteristics of the valves, efficient reservoir simulation models are required. This paper is aimed at presenting the specific developments introduced in a multipurpose industrial reservoir simulator to simulate such wells equipped with intelligent completions taking into account the pressure drop and multiphase flow. An explicit coupling or decoupling of a reservoir model and a well flow model with intelligent completion makes usually unstable and non-convergent results, and a fully implicit coupling is CPU time consuming and difficult to be implemented. This paper presents therefore a semi-implicit approach, which links on one side to the reservoir simulation model and on the other side to the well flow model, to integrate ICD and ICV.

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Smart Reservoir Management with Real-Time Monitoring in an Offshore Carbonate Digital Oil Field under Miscible Gas Injection

Javid

Bascialla

Sainz

et al. 2020

Day 2 Tue, November 10, 2020

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This Green Field was commissioned and put on production few years ago and subsequently within a few months Miscible Hydrocarbon Gas injection was started on a Field scale. It is a modern Digital Oil Field having two artificial islands built to drill all its field development wells with advanced completions such as ICV, ICD and Permanent Downhole Gauges in all Oil Producer Wells with automated multi-phase flow metering (MPFM). This paper will describe the utilization of real-time data for better and efficient Field/Wells Monitoring along with quick and smart reservoir management decision-making & improved reservoir characterization. Real-time Dashboards (some of these were published last year, [1]) are utilized for robust screening of wells as per predefined rules and alerting Engineers for any wells, which are close to violating any of the Reservoir Management Guidelines, after QC and verification timely decisions, are made to avoid those violations. These Reservoir Management Guidelines for wells BHP & WHP are taken from Fluid Model (i.e. Equation of State) since the Field has a challenging considerable vertical compositional gradient for each of its reservoirs. The Guidelines are accordingly adjusted whenever a new verified information from PLT or PVT is available. Inter-well Gas Tracers Project implementation on Field scale is ongoing, where Tracers will be injected in all Gas Injection Wells/Strings to improve Reservoirs surveillance, Reservoirs understanding, Gas Injection Management, future wells locations and completion strategy etc. Real-time MPFM Flow Tests & Permanent Downhole Gauges Pressure data is utilized for Real-time Pressure Transient Analysis (PTA) and well shut in time for PBU is therefore optimized. Moreover, All Field/well Shut Down duration opportunities are also utilized for real-time Pressure Build-up (PBU) analysis & recording WHCIP & BHCIP surveys for Oil Producer wells and therefore considerable cost of running Memory gauges and intervention operations is saved. This paper shows examples of PTA data interpretation through real time data that improved decision-making and optimize the performance of each well. The benefits of implementing a digital oil field philosophy for improved decision making in order to maximize oil recovery in a challenging enhanced oil recovery offshore project is also discussed. Successful & Smart Reservoir Management is a result of collaborative and multiple discipline Team Work.

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Comprehensive ICD/ICV Completion Design Workflow Practiced in Green Oilfield Offshore, Abu Dhabi

Cited by 4 publications

References 22 publications

Flow simulation for a horizontal well with slotted screen and ICD completions based on the wellbore–annulus–reservoir model

Flow simulation for a horizontal well with slotted screen and ICD completions based on the wellbore–annulus–reservoir model

A semi-implicit approach for the modeling of wells with inflow control completions

Smart Reservoir Management with Real-Time Monitoring in an Offshore Carbonate Digital Oil Field under Miscible Gas Injection

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