Enhancing Production Performance of Horizontal Wells in Naturally Fractured Carbonate Reservoirs Using Inflow Control Devices (ICDs)

Al-Alyan, Essam M.; Almutairi, Saad; Ukaegbu, Orji O.; Ogunsanwo, Oloruntoba

doi:10.2118/174727-ms

SPE Annual Technical Conference and Exhibition 2015

DOI: 10.2118/174727-ms

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Enhancing Production Performance of Horizontal Wells in Naturally Fractured Carbonate Reservoirs Using Inflow Control Devices (ICDs)

Essam M. Al-Alyan

Saad Almutairi

Orji O. Ukaegbu

et al.

Abstract: The use of Inflow Control Device (ICD) in long horizontal wells drilled in naturally fractured carbonate reservoirs (NFR) has helped alleviate premature water breakthrough and control high water production. The main factors associated to premature water breakthrough and high water cut in NFR wells are the uncertainty in fracture conductivities and location of fracture corridors crossing or nearby to the horizontal wellbore.In this paper, an assessment is provided of the production performance review conducted … Show more

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Cited by 5 publications

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A Robust Framework for ICD Design in a Giant Field Using 4-D Dynamic Modeling

Ogunsanwo

Lee

Isichei

et al. 2017

SPE Middle East Oil &Amp; Gas Show and Conference

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In this study, a review of production performance of four existing horizontal producers equipped with Inflow Control Device (ICD) completions was conducted using 4-D dynamic modelling on a sandstone reservoir with high water mobility. The aim of this study was to investigate the optimum regulation degree across ICD completion i.e. the ratio of pressure drop across ICDs to the reservoir drawdown, suitable to delay water breakthrough, minimize water cut and achieve production balance. A single wellbore model was built by populating rock and fluid properties in 3-D around the wellbore for each of the studied wells. The model was then calibrated to the measured production log flow profile and bottomhole pressure profile for the deployed ICD completion in each well. Thereafter, several ICD simulation cases were run at target rates for a production forecast of 4 years. An optimum ICD case for each well was selected on the basis of water breakthrough delay, water cut reduction and incremental oil gain. The study results showed that there is a correlation between reservoir heterogeneity index, well productivity index (PI) and optimum regulation degree required across ICD to achieve longer water breakthrough delay and better water cut control. In general, high heterogeneity, high PI wells require higher regulation degree across ICD of close to one; medium heterogeneity, low PI require regulation degree across ICD of between 0.3 – 0.45 while low heterogeneity, low PI, require very low regulation degree of between 0.1 – 0.15. Based on study results, a new ICD design framework and correlation chart were developed. This framework was then applied to two newly drilled horizontal producers to test the applicability of the workflow in real time ICD design scenarios and positive results were achieved. Given the significant number of ICD completions deployed yearly, this new ICD design framework would provide guidance on how much pressure drop across ICD is required during real time design for newly drilled or sidetrack wells and would ultimately ensure maximum short and long term benefits are derived from deployment of ICD completions.

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A Robust Framework for ICD Design in a Giant Field Using 4-D Dynamic Modeling

Ogunsanwo

Lee

Isichei

et al. 2017

SPE Middle East Oil &Amp; Gas Show and Conference

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Influence of Surface Choke on Water Cut and Flow Profile in Horizontal Wellbores Intersecting Fractures and Super-Ks

Sulaiman

Krinis

Shehri

2019

SPE Middle East Oil and Gas Show and Conference

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The surface choke has been utilized in the oil industry to control withdrawal rates per well and to optimize production especially after water breakthrough. However, as found out from this study, applying undue restrictions in horizontal wellbores intersecting high permeability features can have an adverse impact on well performance and unnecessarily lock oil potential. This paper investigates the effect of surface choke on water cut and flow contribution along horizontal wellbores that encountered natural fractures and high permeability streaks (Super-Ks). The study considered different down-hole completions; open-hole and cased-hole. The investigation was carried out using Multi Phase Flow Meter (MPFM) measurements at different choke sizes in addition to production logs (FSI), wellbore simulation modeling, and real-time data. Instant data monitoring was instrumental in insuring stabilization of sub-surface static pressure while performing many rate tests at different choke sizes. Moreover, it flagged the role of rate stabilization on water cut behavior and rate data quality. The presence of conductive fractures and Super-Ks substantially influences the flow profile and water cut of horizontal wellbores. These features create high permeability conduits along wellbores such that they dominate production and may cause some matrix sections to contribute little or nothing as observed on FSI profiles. The effect of fractures on production from less permeable sections in the wellbore was investigated at different operating rates using horizontal wellbore simulation modeling. Both MPFM measurements and FSI logs showed that water cut from horizontal wells, affected by fractures and/or Super-Ks, can decrease if they're flowed at higher rates. Upon reviewing and analyzing data from numerous FSI logs, the study has been able to relate the water cut and surface choking to the well productivity index (PI). Consistently, wells with PI more than twice the averaged matrix PI were found to always perform better at bigger choke sizes. By choke relaxation, the water cut decreased by up to 22% while increasing oil production. Wellbore modeling also suggested that the influence of a fracture on flow contribution from remaining sections in the wellbore can be minimized if the well is operated at higher rates. Restrictive surface chokes were found to disproportionately affect lower permeability sections compared to conductive fractures or Super-Ks which in most cases were invaded by water after water breakthrough. Relaxing these surface chokes allowed more contribution of dry oil from the lower permeability sections, hence the increase in overall oil production and drop in water cut in the affected wells.

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Optimal Downhole Flow Control Completion Designs in a Fractured Carbonate Reservoir Using Reservoir-Centric Simulation Approach

Amjad

Ogunsanwo

Bawazir

et al. 2020

SPE Annual Technical Conference and Exhibition

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Long horizontal wells in naturally fractured carbonate reservoirs often exhibit very high water-cut within months of production because of the early arrival of water from natural fractures. Passive inflow control devices (P-ICDs) have been used globally to balance influx, delay water or gas breakthrough to prolong well life. However, some wells have continued to experience high water-cut despite the control measures. Image log review has revealed the uncertainty is in the identification of fractures and its conductivity networks. Two additional zonal control technologies are presented in this paper: on/off ICDs and intelligent (IC) or smart completions in comparison. A software-based 3D reservoir model was built to represent a horizontal oil-producer in a fractured carbonate reservoir penetrating a thin oil rim. The first model simulated well production performance in a well with on/off ICD. Intervention was replicated in time (i.e., taking longer) to shut-off ICDs. The second model evaluated production forecast over the same period for the same well, this time equipped with an IC in the open hole (OH). Actions in this case were taken right away from the surface (i.e. without downhole intervention) to identify and restrict or shut-off intervals with water breakthrough. Time-lapsed 3D reservoir model calibration is possible with ICs as they provide real-time downhole pressure and temperature across each interval. The timely control of zonal valves from surface actuation reduced production of water or gas. On/off ICDs, on the other hand, necessitated scheduling a production log (PL) to confirm the interval of water or gas breakthrough and performing coiled-tubing (CT) intervention to shut-off the problematic zone. Intervention comes at cost of interrupting well production and reducing net oil recovery. A simplified cost-benefit analysis of both cases showed that despite a higher initial capital investment in ICs, well operating costs were substantially lower with higher oil recovery. In IC solution, costs for running production logs and intervention tools were eliminated and so was the risk of losing these tools in the hole and the loss in production during the intervention period. Continuous monitoring of downhole pressure data helped reservoir characterization and prediction of reservoir production behavior without compromising production on-stream time. A comparison of different reservoir flow control devices suggests that ICs are the optimal choice in some fractured carbonate reservoir conditions. They provide real-time monitoring of each producing zone and surface control of the flow control valve (FCV) settings in real-time as reservoir performance changes. They enable production testing evaluation—without production logging and interventive shifting with CT, i.e. to determine the source of water entry and optimization of multi-zone production without downhole intervention.

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Enhancing Production Performance of Horizontal Wells in Naturally Fractured Carbonate Reservoirs Using Inflow Control Devices (ICDs)

Cited by 5 publications

References 11 publications

A Robust Framework for ICD Design in a Giant Field Using 4-D Dynamic Modeling

A Robust Framework for ICD Design in a Giant Field Using 4-D Dynamic Modeling

Influence of Surface Choke on Water Cut and Flow Profile in Horizontal Wellbores Intersecting Fractures and Super-Ks

Optimal Downhole Flow Control Completion Designs in a Fractured Carbonate Reservoir Using Reservoir-Centric Simulation Approach

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