To address the need for better understanding of multiphase fluid flow behavior through passive inflow control devices (PICDs), two-phase (oil-water) full-scale flow loop testing on helical and a new ICD design, "Hybrid" has been completed. The primary testing objective was to generate a comprehensive two-phase (oil-water) data set of flow performance curves for the helical ICD and the hybrid ICD. The test included a broad range of flow tests with varying viscosities, water cuts and pressures. The results are presented in an innovative manner using isobaric plots (isobars lines with trend lines for each viscosity value) and Reynolds number vs. Flow Coefficient plots, which can be used to easily compare different ICD performances. Test results confirm that for oil-water flow, a viscosity break point for the helical ICD occurs at 2 centipoise (cP) of medium oil. Below this break point the helical ICD does not promote water production in two-phase flow. Above this viscosity break point, the helical ICD exhibits a physical phenomenon where, at water cuts above 30%, the total flow increases at any given pressure drop promoting water flow. With regards to two-phase oil-water fluid flow, the hybrid ICD performs independently of viscosity for the range tested (up to 200 cP - maximum flow viscosity tested at the lab).The hybrid ICD consistently creates more resistance to water flow than to oil flow, causing total flow to gradually decrease at constant pressure as water cut increases. This effect was more apparent at higher pressure regimes. The functional break point of the hybrid ICD is determined to be above 200 cP. Introduction A comprehensive two-phase (oil-water) data set of flow performance curves for the helix inflow control devices (ICDs) and hybrid ICDs was conducted through extensive laboratory testing to identify the threshold viscosity, and to quantify single and multiphase model validity. These test results confirm that the threshold viscosity is 2 centipoise (cP). At viscosities greater than 2 cP, the test results confirm previously published findings that the helix design exhibits preferential production of water for a given pressure drop in a two-phase flow. Additionally, results verify that the helix ICD behavior exhibits correlation to the single phase model but requires a correction due to non-constant flow coefficient, and does not exhibit correlation when the fluids are multiphase, especially at higher viscosities.

Summary Openhole packers have been shown to be very effective in many different applications, including curing losses, controlling high-permeability zones and fractures, improving equalization in passive- and active-inflow-control-device (ICD) completions, and, most importantly, controlling water and gas production. The use of these tools has increased exponentially in the last few years and will continue to grow. This paper summarizes the most important findings and lessons learned about the role of zonal isolation in advanced horizontal completions. More than 12 years of experience using reservoir-optimized completions, including passive or active ICDs and openhole packers, in more than 1,000 wells and several tens of different fields around the world has led to the accumulation of best practices and rules of thumb. The approach for openhole packers has changed markedly with time, along with the industry learning about the importance of these tools in advanced horizontal completions. Important considerations have been generated to design horizontal completions under different fluid properties, reservoir uncertainties, and optimum operational considerations allowing for equalization of flow along the entire length of the horizontal section. These best practices came from extensive run history and lessons learned, and it has been found that openhole packers often play the most critical role for a completion's success. The availability of a wide range of new zonal-isolation tools makes it easier for operators to obtain the best and most-cost-effective solution for each application. Openhole packers for compartmentalization are key for success in many applications and offer benefits for inflow and annulus flow control. An extremely important consequence is the ability to control gas or water after breakthrough. This has been proved from analyzing a significant amount of production logs post-installation. Actual well-performance data and simulations will be shown to support the discussion and illustrate concepts and findings.

Openhole packers have been proven to be very effective in many different applications, including curing losses, controlling high-permeability zones and fractures, improving equalization in passive and active inflow control device (ICD) completions, and, most importantly, controlling water and gas production. The usage of these tools increased exponentially in the last few years and will continue to grow. This paper summarizes the most important findings and lessons learned about the role of zonal isolation in advanced horizontal completions. More than 12 years of experience using reservoir-optimized completions, including passive or active ICDs and openhole packers, has led to the accumulation of best practices and rules of thumb. The approach for openhole packers has changed markedly with time, along with the industry learning about the importance of these tools in advanced horizontal completions. Important considerations have been generated to design horizontal completions under different fluid properties, reservoir uncertainties, and optimum operational considerations allowing for equalization of flow along the entire length of the horizontal section. These best practices came from extensive run history and lessons learned and it has been found that openhole packers often play the most critical role for a completion’s success. In addition, the availability of a wide range of new zonal isolation tools on the market makes it easier for operators to obtain the best and most cost-effective solution for each application. Openhole packers for compartmentalization are key for success in many applications and offer benefits for inflow and annulus flow control. An extremely important consequence is the ability to control gas and/or water after breakthrough. This has been proven from analyzing a significant amount of production logs post-installation. Actual well performance data and simulations will be shown to support the discussion and illustrate concepts and findings.

Horizontal wells have provided operators a way to maximize reservoir contact, improve sweep efficiency and well productivity. Conventionally completed horizontal wells present a high risk of gas cusping and water coning that can significantly affect the well's effectiveness. Preventing early unwanted fluid breakthrough is key to the well's success, hence it is critical that an even production influx profile along the entire wellbore is achieved. The production profile along the wellbore is affected by various parameters, including: heterogeneity with respect to the permeability and reservoir pressure along the wellbore, the presence of fractures, and frictional effects. Inflow control devices (ICDs) were developed to delay gas/water breakthrough, maximize sweep, and reduce — even potentially eliminate — future well intervention. ICDs have become a mainstream completion tool in Saudi Arabia. With each ICD completion deployment, a better understanding is gained with respect to deployment and installation of the lower completion, as well as a greater insight to how to achieve optimum reservoir management. Analysis gained from the previous wells has helped capture a substantial amount of best practices and lessons learned. This paper intends to capture the lessons learned after more than 10 years of deployment of inflow control completions in Saudi Arabia. The main topics that are to be discussed are: ICD types, the optimum operating envelope, and new technological advancementsOptimum ICD design approachOpen hole packersDeployment systemsBest operational practices and their potential impact This paper provides a guideline for designing a well with ICD completions, and explains how the advancement in technology impacts cost, time and reservoir management.

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