Inflow control devices (ICDs) address uneven inflow along horizontals laterals. Heterogeneities in reservoir permeability and/or completion frictional effects are often cited as reasons behind uneven flow profiles along these wells. The configuration of the ICDs is designed to uniformly distribute flow along the lateral. Recently, demand for ICDs in injection applications has risen, leading to design initiatives on the part of operators and service companies that attempt to address more rigorous conditions (i.e., pressure and temperature in acidizing, SAGD, cyclic steam stimulation). In carbonate reservoirs it is imperative to stimulate wells to enhance productivity and bypass possible induced damage during the drilling and completion phase (SPE 171750MS). The problem with current passive ICDs is that they restrict flow equally in the injection and production direction. Given the emphasis to reduce operational expenditures, rig time could drastically be reduced if the ICDs allowed a larger volume of flow to pass through during injection. This enables reduction in the operational time tied to intermittent acidizing cycles. The design discussed in this paper demonstrates the flow bias phenomenon for fluids flowing in the injection mode. Typically, to achieve this preferred flow a shifting sleeve would have to be activated, which requires an extra trip and introduces operational risk. In addition, the device was designed to withstand said cycles during acidizing while maintaining expected performance during the production phase. As such, the design was tested per an operator's detailed program, which required the device to maintain a certain level of durability and performance throughout the well life.

Demand for inflow control devices (ICDs) in injection applications is increasing, leading to design initiatives by operators and service companies. These initiatives address the more rigorous conditions of injection applications including acidizing, SAGD, and cyclic steam stimulation. This paper will demonstrate the success of an iterative design and qualification process to develop a robust tortuous path ICD that can withstand higher pressures and higher stimulation rates operators desire for injection applications. The design process started with computation fluid dynamics (CFD) modeling to predict the stimulation flow performance and resulting pressure gradient underneath the ICD's outer housing. This information was input to the finite element analysis (FEA) model to determine the stress and deformation of the housing. Results of a dynamic flow test with strain gages attached to the housing were compared to the simulated deflection. Additional iterations of the FEA model resulted in the final ICD design. An endurance test verified the final design could withstand full length stimulation operations. The implementation of the design and qualification method enabled the ICD to withstand higher injection rates without losing any ICD functionality. Overall, the maximum allowable injection rate was increased by 50% compared to the proven ICD design used in production wells. Previous ICD qualification testing mainly involved characterizing the ICD in production, not the rigorous conditions during stimulation. Thus, designs were not subjected to such intensive mechanical integrity testing. However, in carbonate reservoirs it is often imperative to stimulate wells to bypass damage induced during the drilling and completion phases [Bachar, November 2014]. As stimulation techniques for horizontal wells continue to improve, it is important for well completion technology to keep pace. Differential improvements in ICD design enable a much wider range of well stimulation capabilities increasing well productivity over the life of the well.

The number of inflow control technologies, predominantly organized into passive inflow control devices (PICDs) and inflow control valves (ICVs), are rapidly increasing. The inflow control device (ICD) level of autonomy, or ability to automatically choke back unwanted fluid flow, is also considered when classifying the device, creating a sub-category of PICDs known as autonomous inflow control devices (AICDs). These distinctions can often cause confusion, and currently there is no agreement about the metrics for judging the performance of an ICD. This confusion negatively affects the industry's ability to identify application-specific criteria and deliver fit-for-purpose ICDs. A recent collaboration has demonstrated the potential for designating ICDs to meet a specific application's unique requirements. When the preferred flow characteristics are identified in advance, these preferences guide the design, testing, and qualification process. In this instance, the needs of cyclic steam stimulation were met by a viscosity-insensitive, autonomous device that was tailored to this particular application. The design included different options of an inflow control mechanism and a wide range of flow resistance settings. As flow control technologies continue to gain industry acceptance as an effective means of balancing reservoir inflow, understanding the categorization and corresponding design process becomes critical. Because there are no current industry standards for ICD design, this paper should serve as guidance for industry personnel to identify flow control requirements and deliver a suitable solution.

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The re-development of a giant offshore field in the United Arab Emirates (UAE) consists predominantly of four artificial islands requiring in most cases extremely long horizontal laterals to reach the reservoir targets. Earlier SPE technical papers (1,2) have introduced the development, testing, qualification, and deployment of the plugged liner technology using the dissolvable plugged nozzles (DPNs). The use of DPN plugged liner technology has resulted in CAPEX savings and enhanced production performance. The benefits of DPN technology are its simplicity along with its cost effectiveness. However, the dissolvable material has some limitations, such as pressure rating and dissolution time, which are fluid chemistry dependent. To overcome these limits, a new Pressure Actuated Isolation Nozzle Assembly (PAINA) was developed as an alternative to the plugged liner tool for applications where a higher pressure rating is required, as well as on demand opening. Furthermore, the new PAINA also functions as a flow control device during injection and production, enhancing acid jetting effects during bullhead stimulation and reducing brine losses during liner installation. Liners with PAINAs can be run to TD similar to blank pipe: fluids can be circulated through the inside of the liner without the need for a wash pipe. Once on bottom, non-aqueous drilling fluid is displaced to brine without actuating the isolation mechanism. When the well is ready for production or injection, pressure is applied and the isolation mechanism is activated to establish communication between well and reservoir. These tools were successfully run as flow control devices in water-alternating-gas (WAG) pilot wells. The planning and execution of the initial application will be discussed, along with the tool development, qualification testing, and lessons learned. The key advantage of this technology is in extending plugged liner applications to cases where other pressure-operated tools are included as part of the liner lower completion. Pressure can be applied to the well multiple times without activating the isolation mechanism as long as the applied pressure is below the actuation pressure.