How Fluids Performance Ratio Analysis of ICD/AICV can be used to Analyze Oil Production, Unwanted Water and Gas Breakthrough in Carbonate or Sandstone Reservoirs

Ismail, Ismarullizam Mohd; Bjerke, Anita; Mathiesen, Vidar

doi:10.2118/213189-ms

SPE Latin American and Caribbean Petroleum Engineering Conference 2023

DOI: 10.2118/213189-ms

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How Fluids Performance Ratio Analysis of ICD/AICV can be used to Analyze Oil Production, Unwanted Water and Gas Breakthrough in Carbonate or Sandstone Reservoirs

Ismarullizam Mohd Ismail

Anita Bjerke

Vidar Mathiesen

Abstract: Enhanced oil recovery technique for carbonate or sandstone reservoirs using inflow control technology are often affected by undesired production of water and gas. Limited density and viscosity differences between oil, water and gas is often a challenge for most autonomous and passive inflow control technology due to limited fluids performance ratio between oil, water and gas when breakthrough happen. The fluid performance ratio describes how the ICD (Inflow Control Device) and AICD (Autonomous Inflow Control D… Show more

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2024

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Cited by 4 publications

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Design Configuration for Autonomous Inflow Control Valve Technology for Newly Drilled Well in a Mature Field in Malaysia – Model vs Reality

Bandara,

Ismail,

et al. 2024

Day 1 Wed, April 17, 2024

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Design of an ICD (Inflow Control Device) completion is initially determined based on the static and dynamic models prepared during pre-drilling stage of the well. However, actual well properties available post-drilled are quite different from the pre-drilled properties, and the completion must be optimized. The objective of this study is to address the challenges on pre- and post-completion designs which was conducted for a gas and water control application in redevelopment phase infill well in a mature field in Malaysia. All types of ICD completions are designed based on the static simulation for selected time steps of a dynamic simulation. The autonomous inflow control valve (AICV) is an advanced ICD that can also choke/close unwanted gas and water. The number of AICVs are determined based on the initial maximum oil production rate, despite permeability and gas/water saturation. Therefore, several sensitivities were conducted to determine optimum production rate with an AICV completion. The compartmentalization and distribution of AICVs mainly depended on the well constraints. Although, the required number of AICV are same for the post drill completion, packers and AICV joint placement were adjusted based on the drilling log data. Drilling logs indicated that permeabilities of the post-drilling were about 1/10 of the expected permeabilities of the model and high permeability zones were concentrated to localized zones compared to distributed high permeability in the model. Localized high permeable zones create challenging situations to place the required number of AICV joints in respective compartments due to length constraints. The completion design was re-optimized based on the new permeability profile and new constraints. Packers were placed in low permeability zones to maximize the effect of zonal isolation. Additional packers were installed to delay the gas transport to oil producing compartments in case of a gas breakthrough in neighboring compartment. The number of AICV joints utilized in the well was lower compared to the originally predicted number of joints due to shorter TD of the well. For the well, the number of AICV joints utilized was 38 out of 45 joints. The well started production with desired oil rate at 1500 BOPD with minimal gas and water production with productivity index (PI) 2x better than expected.

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Design Configuration for Autonomous Inflow Control Valve Technology for Newly Drilled Well in a Mature Field in Malaysia – Model vs Reality

Bandara,

Ismail,

et al. 2024

Day 1 Wed, April 17, 2024

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Mitigating Early Water and Gas Breakthrough: Autonomous Inflow Control Valve Applications in the Balder Field

Luciani,

Wiranda,

Samosir

et al. 2024

Day 1 Wed, April 17, 2024

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Summary The Balder field is typically completed with long, horizontal wells. In the initial development of the field the wells were typically completed with stand-alone screens (SAS), in later developments they were completed with nozzle inflow control devices (ICD), and recently with autonomous inflow control devices (AICD) to mitigate early water breakthrough. The purpose of this study is to assess the implementation of autonomous inflow control valves (AICV) to further mitigate unwanted fluid production and enhance the long-term oil recovery in the field. The study employed numerical reservoir simulation tools and static wellbore simulators to model the Balder field. Simulations were performed both on a sector model around the target well, to reduce simulation time, and on the full-field reservoir model. Two different dynamic reservoir simulators were used. Reservoir simulation tools were used to compare a base case scenario of SAS completion with AICVs. AICV wells require proper compartmentalization, and 3, 5, and 7 compartment scenarios were considered. Simulation results show how the AICV completion retains the reservoir pressure in the initial years of production compared to the SAS. This leads to a significant reduction in early gas breakthrough, reducing the overall gas production. Moreover, the water production after breakthrough was also reduced. Water and gas production is reduced more by having more compartments, which indicates that proper isolation of the wellbore is key to optimize the production of a well. The simulation results from a hydrodynamic sector model aligned with the full field model, and the near wellbore model reproducing observed pressure drop across the AICVs assessing the robustness of the workflow for device modeling in simulators. The study provides a workflow for performing dynamic reservoir simulations using AICV completion. It covers how compartmentalization affects the overall productivity of a well, and how AICVs work for optimizing the inflow from the reservoir to an oil well. Moreover, the study analyzes the impact of the reservoir model grid size on the lower completion evaluation. Important design decisions are based on physics in the reservoir and can be applied to other fields.

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Increasing Recovery and Lowering CO2 Intensity Through Use of Autonomous Inflow Control – A Case Study from the Norwegian Continental Shelf

Halvorsen,

Martiniussen,

Nilsen

et al. 2024

SPE Annual Technical Conference and Exhibition

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The aim of this paper is to demonstrate how the adoption of autonomous inflow control (AICD) can lower water production and CO2 intensity in a field situated on the Norwegian continental shelf. The study outlines the process starting from device qualification and testing in a flow loop, followed by evaluation through modelling and reservoir simulations, then well planning to optimize AICD implementation, and finally the measurement of the effect in several wells. Breidablikk is an oilfield located on the Norwegian continental shelf that commenced oil production in October 2023. The oil reserves are at a depth of about 1750 meters, forming a thin layer that sits atop a strong water aquifer. Prior to production, a range of AICD solutions aimed at water reduction were evaluated, including qualification, and testing of the devices in a flow loop to obtain their flow performance data. This data was subsequently used as input in multiple reservoir simulations to determine the optimal distribution of AICDs in the wells. The wells are closely monitored to confirm that the expected AICD behavior has been achieved. The Breidablikk wells consist of long horizontal sections, both single and multilaterals, with lengths of up to 1600 meters. They are equipped with screens, various inflow control devices, blank sections, and swell packers. Following implementation and production start-up, measured flow rates and pressures are compared against the expected AICD performance. The lower completion design is optimized using a steady-state well simulator and the use of a dynamic reservoir simulator to provide expected production profiles. During the stepwise clean-up of the wells and branches, differential pressure and oil rates are used to measure well clean-up and AICD efficiency. The pressure drop across the AICDs is determined based on down hole pressure, plotted versus initial well test rates, and is consistent with laboratory tests under similar conditions. Chemical tracers have also been used to verify clean-up during flow performance evaluation. Based on the successful implementation, there is a good basis for planning and optimizing use of AICDs in future wells at Breidablikk. The reservoir drainage strategy for Breidablikk depends upon implementing artificial lift and utilizing the well designs mentioned earlier. Production of the wells at minimal gas lift rates, in combination with on/off well production, allows for higher NPV and recovery to be attained throughout the anticipated field lifetime. To ensure a successful implementation, step rate tests are performed to affirm the AICD flow characteristics determined through lab testing and simulations.

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How Fluids Performance Ratio Analysis of ICD/AICV can be used to Analyze Oil Production, Unwanted Water and Gas Breakthrough in Carbonate or Sandstone Reservoirs

Cited by 4 publications

References 5 publications

Design Configuration for Autonomous Inflow Control Valve Technology for Newly Drilled Well in a Mature Field in Malaysia – Model vs Reality

Design Configuration for Autonomous Inflow Control Valve Technology for Newly Drilled Well in a Mature Field in Malaysia – Model vs Reality

Mitigating Early Water and Gas Breakthrough: Autonomous Inflow Control Valve Applications in the Balder Field

Increasing Recovery and Lowering CO2 Intensity Through Use of Autonomous Inflow Control – A Case Study from the Norwegian Continental Shelf

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