Multi-Phase (Oil-Water) Loop Flow Test for Helical and Hybrid Passive Inflow Control Devices

Horizontal wells drilled in heterogeneous reservoirs present several challenges for reservoir management. Issues like early water breakthrough and inefficient drainage around the well in a reservoir with high contrast in permeability are very common in horizontal wells. An effective approach to address the challenges of horizontal wells and to increase the oil recovery is to complete the wells with inflow control device (ICD) technology. Most ICD technologies available in the market are passive inflow control devices that do not have the ability to change properties when unwanted fluids break through. The new ICD not only incorporates the benefits of passive ICD technology, it also incorporates sliding sleeves in the module that can be closed whenever the ICD starts producing water. This helps maximize the oil production from the well and reduces the problems related to handling of water at the surface facilities. This paper will demonstrate the effectiveness of the new hybrid ICD design. It is novel viscosity insensitive and may provide higher restriction to water over oil, and the successful operation of the sliding sleeve feature through a field case of a well drilled in a carbonate field in Middle East. Bottomhole pressure and weight indication observed through specialized fiber optic-installed coiled tubing confirmed the operability of technology by proper opening and closing of sliding sleeve. A fluid flow profile recorded by a production logging tool (PLT) on the same CT proved that the completion effectively equalized flow along the wellbore and will delay eventual water breakthrough while still producing at the desired production rates. PLT proved that the custom-designed completion with its appropriate number of compartments, number of ICD joints and flow resistance rating, achieved an optimized ICD completion.

Rubiales and Quifa are the Colombia's major heavy oilfields (oil gravity ranges from 11.3 to 14.4° API) with a current oil production of more than 260 MSTB with an oil viscosity ranges from 370 to 730 centipoises. Horizontal well technology is used to drill through unconsolidated sandstones with an active and strong aquifer, under primary depletion. Since 2006, 604 horizontal producer wells have been drilled and completed using slotted liner in open hole. The high water production rate from the beginning of the operation in the horizontal wells is the main problem to be controlled in the Rubiales and Quifa fields, due to the high cost of produced water treatment and other factors. Water production is inevitably associated with the oil production; however one of the biggest challenges is to delay the water production as much longer as possible. Rubiales and Quifa actually have a large number of closed wells that have reached its economic limits, mainly by high water production. This production imbalance is being addressed in the new horizontal wells, using inflow control devices (ICDs). The ICDs is placed in each screen joint to balance the production influx profile across the entire lateral length and compensate the permeability variation and therefore the productivity of each zone. In 2012, a pilot test has been designed and implemented in Rubiales field with three horizontal wells using passive ICDs completion. The performance of the ICD's is found to reach the highest cumulative oil production compared to neighboring wells. The main purpose of this paper is to detail the selection process design and results evaluation for the use of the passive ICDs in horizontal wells at Rubiales and Quifa Fields, heavy oil reservoirs.

Advances in drilling and well construction technologies have enabled extended-reach horizontal and multilateral wells to increase reservoir contact and improve recovery. Completion systems with passive inflow control devices (ICD) or intelligent wells are used to optimize and control inflow from the compartments or laterals. ICD completions are passive systems with torturous paths or orifices designed to choke back inflow from dominant zones and equalize influx along the wellbore. ICDs combined with openhole packers provide very fine compartmentalization of the open hole and it is common to have completions with 40 inflow compartments in some extended-reach wells. ICD completions require well intervention to close zones with high water or gas. Intelligent completions, on the other hand, have downhole valves that can be remotely operated from surface. The requirement for downhole control lines and penetrations at the wellhead and packers has limited the number of downhole valves to a maximum of six in a well. This limitation excludes a significant number of applications where greater compartmentalization can yield superior well performance. The industry has recently developed innovative completion systems that increase the number of surface-controlled downhole valves while minimizing the number of downhole lines. These technologies improve completion design while overcoming limitations like the number of control lines, feedthrough ports on packers and wellhead. Saudi Aramco has recently installed an all-electric intelligent completion with 8 downhole active flow-control devices (AFCD) controlled via a single downhole control line. This installation is currently the world record for the highest number of inflow control valves installed for an intelligent completion. This paper presents details of technology development, evaluation, completion design, installation and in-well testing of the all-electric intelligent completion system in a multilateral well. The paper presents the novel completion design with redundancies, system components, advantages of the chosen technologies and the completion method. The section about the planning phase of installation highlights steps taken to ensure successful execution of the job while minimizing operational risks associated with the deployment of the new technology. Finally, the execution phase of the installation is presented with special emphasis on procedures and actions during installation to improve operational efficiency and minimize health and safety (HSE) risks. Thorough design, planning and execution of the job yielded the successful installation of an advanced and complex intelligent completion system in an efficient and safe manner. All-electric intelligent completion systems capable of controlling multiple downhole valves are anticipated to increase well life and recovery through improved downhole monitoring and control. This system can control as many as 27 AFCDs on a single electric control line.

In an offshore oil field in the southern East China Sea, the formations are sandstone and consist of six horizons, with specific flow unit characteristics and different aquifer support strengths. The operator intended to optimize the production with a permanent simple completion, in commingled production. However, the differences in reservoir properties and aquifer support presented a challenge for maximizing the oil recovery and delaying the water cut without resorting to well intervention. Passive inflow control device (ICD) technology was used to balance the influx from the different formations and hence maximize oil recovery while delaying the incremental water production, and production data validated the benefits of the application by showing a water cut of 50%, in contrast to the expected value of 90% (without the ICD completion), with the same estimated amount of cumulative oil production. Such a benefit is accrued by restricting fluid withdrawal from high-conductivity zones or with strong water drive, while providing enhancements to contribution from lower conductivity zones or zones with weaker water drive. This method is not new in itself, but it has not been used before in a permanent completion system where well interventions had not been planned. Multiple production iterations using numerical reservoir modeling of several completion options were performed and showed a 31.3% oil recovery improvement over the base scenario (all zones commingled without flow control devices).

Horizontal well completions are often equipped with Inflow Control Devices (ICDs) to optimize flow rates across the completion for the whole length of the interval and to increase the oil recovery. The ICD technology has become useful method of optimizing production from horizontal wells in a wide range of applications. It has proved to be beneficial in horizontal water injectors and steam assisted gravity drainage wells. Traditionally the challenges related to early gas or water breakthrough were dealt with complex and costly workover/intervention operations. ICD manipulation used to be done with down-hole tractor conveyed using an electric line (e-line) cable or by utilization of a conventional coiled tubing (CT) string. Wellbore profile, high doglegs, tubular ID, drag and buoyancy forces added limitations to the e-line interventions even with the use of tractor. Utilization of conventional CT string supplement the uncertainties during shifting operations by not having the assurance of accurate depth and forces applied downhole. A field in Saudi Arabia is completed with open-hole packer with ICD completion system. The excessive production from the wells resulted in increase of water cut, hence ICD's shifting was required. As operations become more complex due to fact that there was no mean to assure that ICD is shifted as needed, it was imperative to find ways to maximize both assurance and quality performance. In this particular case, several ICD manipulating jobs were conducted in the horizontal wells. A 2-7/8-in intelligent coiled tubing (ICT) system was used to optimize the well intervention performance by providing downhole real-time feedback. The indication for the correct ICD shifting was confirmed by Casing Collar Locator (CCL) and Tension & Compression signatures. This paper will present the ICT system consists of a customized bottom-hole assembly (BHA) that transmits Tension, compression, differential pressure, temperature and casing collar locator data instantaneously to the surface via a nonintrusive tube wire installed inside the coiled tubing. The main advantages of the ICT system in this operation were: monitoring the downhole force on the shifting tool while performing ICD manipulation, differential pressure, and accurately determining depth from the casing collar locator. Based on the known estimated optimum working ranges for ICD shifting and having access to real-time downhole data, the operator could decide that required force was transmitted to BHA. This bring about saving job time while finding sleeves, efficient open and close of ICD via applying required Weight on Bit (WOB) and even providing a mean to identify ICD that had debris accumulation. The experience acquired using this method in the successful operation in Saudi Arabia yielded recommendations for future similar operations.

This paper describes the use of advanced completions employing passive inflow control devices (ICD) and autonomous inflow control devices (AICD) in multi-zone horizontal wells to improve the distribution of gas injection and to restrict premature production of gas in gas injection soak EOR process for unconventional oil wells. The recovery efficiency of unconventional oil reserves is very low due to the micro-permeability of these reservoirs and rapid depletion of pore pressure proximal to the fractures and wellbore. Several enhanced oil recovery schemes have been proposed to stimulate production and increase recovery efficiency in these reservoirs by injecting gas or carbon dioxide in fracture stimulated, long horizontal wells, and either producing oil from adjacent wells (gas injection flooding drive mechanism), or by back-producing the injectant and reservoir fluids in the same wellbore after a suitable "soak" period (huff and puff). The effective distribution of the injected gas in these wells and the ability to keep the gas in the reservoir to maintain energy can greatly affect the recovery efficiency that can be achieved. Advanced completions utilizing appropriately designed ICDs and AICDs can enhance the performance of these EOR schemes. ICDs can be used to balance the distribution of gas injection along the length of the wellbore, while AICDs can help control the early back-production of gas. The Autonomous Inflow Control Device (AICD) is an active flow control device that delivers a variable flow restriction in response to the properties (viscosity) of the fluid flowing through it. Water or gas flowing through the device is restricted more than oil. When used in a horizontal well, segmented into multiple compartments, this design prevents excessive production of gas after breakthrough occurs in one or more compartments. The implementation of advanced completions in EOR applications has been studied by reservoir and well performance simulation. This proper use of ICDs and AICDs in these applications can significantly improve recovery efficiency without further well intervention. To evaluate the performance of the AICD, a comprehensive multi-phase flow model of the autonomous performance has been developed and workflow created for simulation of performance within the reservoir. This paper will describe the experience with the technology and modelling prediction for EOR projects.

Passive inflow control devices (ICDs) can redistribute the fluid influx (rate per unit length) into the well completion by causing additional pressure drops between the sand face and tubing. The aim of ICDs is to provide an increase in oil recovery and/or net present value (NPV) by reducing unwanted fluids. Software tools exist to model all aspects of ICD, reservoir, well and surface facilities. The challenge addressed by this paper is to provide an understanding of the implications for optimal ICD design over the life of the field, by integrating these models in a consistent manner. This paper investigates different aspects of detailed ICD design on horizontal producers, using a wellcentric reservoir model. The ICD designs from the well-centric models were then applied to a full field reservoir model and integrated studies were then completed. This was achieved by linking several existing software to study the interaction between the ICD design, full field reservoir, well and surface network. Various aspects of the integration of these models were simulated including: artificial lift, water injection strategy and surface network. Predictably, well-centric simulations showed that ICD designs are dependent on the objective function that is being maximized. If NPV is to be optimized, designing ICD strength to have higher production from the heel and toe regions of the well may produce better results than attempting to equalize the inflow for the entire well. Integrated studies showed that artificial lift can be beneficial in combination with ICDs, as the ICDs redistributed the fluid influx into the well, yet the liquid rate reduction due to the additional pressure drop from the ICDs was mitigated. Even when ICDs were shown to be beneficial on standalone reservoir/well models, the design and predicted benefit when a surface network is coupled depends on: how the surface network is operated, surface network constraints and the relative water cut of the well which ICDs are applied to in comparison to the other wells in the field. These results show that ICD design and optimization requires an integrated approach to ensure outcomes that are consistent with the reality of the field.

Steam assisted gravity drainage is a thermal method for enhanced bitumen recovery. In this method, steam is injected to bitumen and heavy oil to reduce the viscosity and make the oil mobile. However, early breakthrough of steam in some parts of the well results in loss of the required amount of steam in contact with the cold bitumen, and poor distribution of the steam chamber. This limits the oil production and increases the SAGD operation cost. Autonomous inflow control valve (AICV) is able to prevent the steam breakthrough and restrict the production of steam. The objective of this paper is to investigate the performances of AICV and passive inflow control device (ICD) in a SAGD production well. This is achieved by developing a dynamic wellbore-reservoir model in the OLGA-ROCX simulator. Reservoir and fluid properties have been specified in ROCX, and the wellbore model has been developed in OLGA. Coupling OLGA and ROCX enable the user to simulate the fluid production from the reservoir into the well. The simulation results demonstrate the significant benefit of AICV in steam to oil ratio (SOR) reduction compared to ICD. Indeed, the simulation results show that utilizing AICV in the SAGD production wells will reduce the steam production by 88% after 300 days of production. From environmental aspect, reduction in the steam to oil ratio by utilizing AICV will reduce the energy demand for steam generation. This will eventually improve the economics of SAGD projects. Also, reduction in the steam and energy demand will consequently contribute to lower the intensity of greenhouse gas (GHG) emissions.

The objective of this paper is to present learnings from designing inflow control devices (ICD) of numerous wells at reservoirs with gas cap with various settings. Key aspects and an efficient ICD design workflow will be presented. The evaluation is based on the application of nozzle ICD for single lateral horizontal well. A synthetic simulation model is utilized to demonstrate example cases. A horizontal well installed with ICD completions improves well performance by equalizing production along the horizontal section to delay water/ gas breakthrough for an oil reservoir with gas cap and aquifer. We utilized an in-house reservoir simulator with advanced complex well options. The first step is to develop an ICD completion design workflow, which includes understanding reservoir permeability heterogeneity, its magnitude and well flow behavior under open-hole completion. At well level, this step is to estimate future major gas and water contribution. Optimum well rate is sensitized for the ICD design. The next step is to focus on ICD design optimization which includes numbers of ICD requirements and compartments, ICD choking. The performance of horizontal well placed under a gas cap was analyzed. An early gas production easily occurs especially for well with high production rate. Controlling gas and water production showed an improvement on oil recovery. We developed the workflow of an ICD completion design optimization for the evaluation. Simulation model with different reservoir properties vertically were created for ICD design case. The ICD design optimization cases with combination of these two factors are evaluated to identify conditions for ICD installation that provide best benefits. Results showed that installation of ICD provides good performance improvement and more even gas oil contact and water oil contact movement toward the wellbore. The ICD design workflow provides a guideline to do the ICD design systematically utilizing reservoir simulation model for an oil rim reservoir. Learnings obtained from the results provide an understanding on the optimal conditions for ICD installation with the goal to ultimately deliver long-life wells while controlling water and gas production in different levels of reservoir heterogeneity and well lengths.

Autonomous Inflow Control Devices (AICDs) are a relatively new technology with the potential to improve the production performance of horizontal wells. The devices control the inflow of reservoir fluid to equalise influx along the length of a horizontal well, and adjust the level of constraint depending on the fluid flowing such that water production is hindered and oil production is promoted. In order to assess the effectiveness of autonomous ICDs compared to passive ICDs, which apply a constant level of restriction, numerical simulations and sensitivity studies were conducted. A detailed model of the lower completion of a theoretical horizontal well was constructed using an Integrated Production Modelling (IPM) simulator. ICDs were represented using an Inline Programmable Element and equations to calculate the pressure drop of a range of different passive and autonomous ICDs were input. Simulations run on this model allowed the pressure drop across each ICD to be analysed, and the liquid rates at the heel and toe of the well to be compared, to assess how effective the ICDs are in promoting a balanced influx from the reservoir along the entire horizontal length of the well. Oil viscosity, heterogeneous permeability, and oil-water-contact levels were then varied to evaluate the behaviour of the ICDs in different scenarios. Analysis of the simulation results suggests that none of the tested ICDs are the best performers in every scenario. The Rate Controlled Production (RCP) Valve AICD is the most effective device in heavy oil wells and in wells with uneven oil-water-contacts. The EquiFlow AICD is the optimum performing devicein a reservoir with heterogeneous permeability, and the nozzle ICD is the most effective device in light oil wells. Comparative study of the behaviour of passive vs autonomous ICDs indicates that there is a difference in performance between these two types of ICDs. In some cases autonomous ICDs can provide significant benefits, where as in others the passive ICDs are just as effective.

This paper discusses the reasons and results of the paradigm shift in NK reservoir management that was necessary in order to increase oil production and safeguard reserves. The new best practices implemented included: field development via horizontal & slant wells, significantly increased water injection with peripheral horizontal wells, Produce High-Inject Low (PHIL) strategy to enable gravity-stable oil production, horizontal re-entries and sidetracks, and the wide adoption of the advanced completion technology of passive inflow control devices (ICDs). Implementation results are provided for those implementation steps where enough time has passed, sufficient to form meaningful conclusions. In order to promote dependable production forecasting and accurate operations results reporting, the QRI-KOC AVAILS+Ô (from "available production") package was developed. It is a powerful tool for the management and developmental planning of NK's set of oilfield assets and its two aspects, production forecasting and operations monitoring, are described below. Introduction The North Kuwait (NK) production area is made up primarily of the Raudhatain (RA), Sabriyah (SA), and Border fields. The major productive horizons are the Mauddud (MA), Upper Burgan (UB), & Lower Burgan (LB) formations. Production for the last 4 years has ranged from 600–700 KBOPD. The operator, KOC (Kuwait Oil Company), faced an overall production challenge, in that the options to sustain and increase production were limited by: (a) lack of new proven acreage, or behind-pipe resources, for development, (b) continuous drop in Pres, approaching Pb, for the reservoirs under depletion or under waterflooding (due to VRR<<1), and (c) gradually diminishing oil rate and rising watercut for the reservoirs with aquifer support, due to oil column invasion by water. Discussion In view of the serious challenges discussed in the Introduction, a paradigm shift, a fundamental change in approach or underlying assumptions, was necessary in order to increase production and reserves. Drilling & Completions. In the Drilling & Completions area, the need to quickly implement advanced well technology required the NK assets to implement best practices in all phases of their well planning and drilling operations. The organization quickly moved away from vertical wells and conventional completions to deviated wells (horizontal and slanted) with ICDs, in order to maximize reservoir contact and well productivity, while controlling water production. This paradigm shift impacted all partners and vendors, who had to shift their work emphasis to better support KOC in both the new horizontal drilling paradigm and the higher oil rate targets. The Drilling & Completions improvements have been gratifying. Figure 1 shows the drilling improvements for the last three years. Figure 2 shows the resulting production improvement (20+ MMBO benefit) in one large reservoir, due to the adoption of horizontal wells and improved drilling and completion practices.

One of the largest oil fields in the GCC was developed in the 1960's. The field was initially produced under natural depletion supplemented by gas injection. The high offtake rates led to a rapid displacement of the gas/oil contact; thus, the field has now been suffering from early gas/water breakthrough and uneven fluid influx along with the horizontal wells. The reservoir has been on production for more than 50 years. Water/gas breakthrough from fractures being the major challenge which negatively affects wells oil production rates. Applying technology which can manage water/gas breakthrough in a cost-effective manner whilst allowing increased oil production was a key goal from operators in this field. Passive Inflow Control Devices (ICD) were introduced to the global oil and gas market in mid/late-1990's, and the first generation of Autonomous ICD (AICD) that can help reduce more unwanted gas or water was first installed in 2007. ICD's successfully demonstrated that they could delay the gas and/or water breakthrough within horizontal wells, but they could not choke gas when the coning/gas-breakthrough occurred and along with limited abilities to stop unwanted water production. To help solve this problem, the Autonomous Inflow Control Devices (AICD-RCP) with a movable disc was introduced to the market and demonstrated reduction of gas production by 20-30% with similar gains in oil production[1]. In this paper, the newest generation of Autonomous Inflow Control Valve (AICV) technology is presented. The AICV technology has a movable piston that can close and reduce the unwanted gas and water production by up to 95%[2]. The application of AICVs discussed herein were deployed within several wells which had extremely high Gas Oil Ratio (GOR) and low oil production. The novel AICV technology can differentiate between fluid types based on viscosity and density. When undesired fluid (gas and/or water) starts to be produced, the AICV chokes the valve flow area gradually until completely shutting off, all without well intervention[3]. Well production performances are documenting the benefits of installing AICV completions. The results demonstrate the AICVs closing the zones with high gas production and favoring oil-rich zones. Majority of evaluated wells demonstrated clearly that the extremely high GOR was reduced; some wells have returned to solution GOR for more than two years, and at the same time, the daily oil production is increased.

This paper presents an analysis of the effectiveness of various downhole completion designs in reducing or deferring water production in a mature field under the presence of an active strong aquifer reservoir. The results of completions using nozzle inflow control devices (ICDs) and fluidic diode autonomous ICDs (AICDs) are compared with conventional openhole and slotted liner completions. As all of these designs were installed in the same field/reservoir, the comparisons provide a meaningful and representative analysis of well production performance to assist in the identification of the most appropriate completion design for future wells and the production optimization of existing ones. The designed vs. actual production performance of inflow control completions providing water control (ICD/AICD) is presented and discussed. The methodology was developed from comparative analysis results of conventional openhole and slotted liner vs. ICD and AICD completions. The analysis was primarily based on elapsed time comparisons for water/oil ratio (WOR) and water cut (WC) and used diagnostic plots to identify the water production mechanisms, historical drawdown (DD), productivity index (PI), and production cumulative performance (oil and water). The corrective actions are described, including operational procedures to reduce skin damage and screen plugging implemented in the Villano-23HST2 (V-23HST2) well, which is the longest horizontal well drilled in Ecuador and completed using AICDs; these corrective actions were based on lessons learned from the Villano-22D (V-22D) well, which included appropriate fluid [brine/oil-based mud (OBM)] conditioning, fluid displacement, filter cake removal, and compatibility testing between screens and the fluid in which the bottomhole assembly (BHA) was deployed. Additionally, this paper evaluates the importance of the design phase, emphasizing the importance of comparing preliminary data (permeability and water saturation) compared to actual results obtained from the initial production test. Finally, as good production results largely depend on successful operational procedures and execution, lessons learned and best practices for deploying downhole completions in future operations for the Villano field in Ecuador are discussed. Although many studies compare ICDs vs. conventional completions, few compare different inflow control technologies, such as ICDs vs. AICDs, within the same reservoir and with similar well conditions. This paper compares various inflow control technologies in the same field with cumulative production data, which verifies the effectiveness of each completion design. Based on these results, a validated methodology for ICD and AICD simulations and design is also described as the basis for achieving good production results.

Non-equalized production influx along the horizontal or inclined wellbore is believed to be responsible for early water/gas breakthrough in oil production wells. Non-equalized water injection distribution has been recognized to cause poor sweep efficiency in waterflooding. The non-equalized fluid flow is attributed to reservoir heterogeneity and frictional pressure drop along the wellbore. A practical means of minimizing the problem is to use inflow control devices (ICD) between isolation packers to adjust the production influx or injection distribution within the isolated compartments. However, the ICDs are passive devices, i.e., once they are set in place in a completion string they cannot be adjusted to ensure equalized flow when reservoir conditions change during oil production or water injection. This paper introduces a new technology called Multi-Node Intelligent Well System (MNIWS) that is under development and will be soon available to the industry. Starting with analyzing the data from an existing horizontal well with an ICD installation, we derived a new completion design for oil production wells using the MNIWS. Computer modeling of well performance shows that the MNIWS technology suite can equalize production influx and delay water breakthrough into the horizontal wellbore more effectively than conventional ICDs; in particular when inflow conditions change during the well's life.

To increase the production and recovery of marginal, mature, and challenging oil reservoirs, developing new inflow control technologies is of great importance. In cases where production of surrounding reservoir fluids such as gas and water can cause negative effects on both the total oil recovery and the amounts of energy required to drain the reservoir, the multiphase flow performances of these technologies are of particular significance. In typical cases, a Long Horizontal Well (LHW) will eventually start producing increasing amounts of these fluids. This will cause the Water Cut (WC) and/or Gas Oil Ratio (GOR) to rise, ultimately forcing the well to be shut down even though there still are considerable amounts of oil left in the reservoir. In earlier cases, Inflow Control Devices (ICD) and Autonomous Inflow Control Devices (AICD) have proven to limit these challenges and increase the total recovery by balancing the influx along the well and delaying the breakthrough of gas and/or water. The Autonomous Inflow Control Valve (AICV) builds on these same principles, and in addition has the ability to autonomously close when breakthrough of unwanted gas and/or water occurs. This will even out the total drawdown in the well, allowing it to continue producing without the WC and/or GOR reaching inacceptable limits. As part of the qualification program of the light-oil AICV, extensive flow performance tests have been carried out in a multiphase flow loop test rig. The tests have been performed under realistic reservoir conditions with respect to variables such as pressure and temperature, with model oil, water, and gas at different WC's and GOR's. Conducting these multiphase experiments has been valuable in the process of establishing the AICV's multiphase flow behavior, and the results are presented and discussed in this paper. Single phase performance and a comparison with a conventional ICD are also presented. The results display that the AICV shows significantly better performance than the ICD, both for single and multiphase flow. A static reservoir modelling method have been used to evaluate the AICV performance in a light-oil reservoir. When compared to a screen-only completion and an ICD completion, the simulation shows that a completion with AICV's will outperform the above-mentioned completions with respect to WC and GOR behavior. A discussion on how this novel AICV can be utilized in marginal, mature, and other challenging reservoirs will be provided in the paper.