Interaction Between Intelligent Well Applications and Reservoir Management—A Comprehensive Thermal Modeling Technology for IWS Well

Sun, Kai; Constantine, Jesse; Coull, Craig

doi:10.2118/115102-ms

Cited by 4 publications

(2 citation statements)

References 13 publications

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“…Since there are two gas zones available above the oil zone, a re-completion plan of IWS auto-gas lift was evaluated to see if this new completion can accelerate production and increase recovery. The developed comprehensive thermal model technology [5][6][7] was again used to evaluate the IWS completion choice. This evaluation includes four parts:…”

Section: Two-zone Iws Auto-gas Lift and Planning Of Completion -Accelmentioning

confidence: 99%

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Intelligent Well Systems—Providing Value or Just Another Completion?

Sun

Constantine

Tirado

et al. 2009

SPE Annual Technical Conference and Exhibition

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This work reviews several typical intelligent well systems (IWS) completed, including a gas producer, oil producer, auto-gas lift oil producer, multilateral IWS producer, and horizontal openhole multi-isolation producer. For each case, the wellbore modeling, completion design, choking operation strategies, and estimated performance will be introduced.Case histories based on the analysis of the well modeling results at the design stage of the IWS completion, including well performance along with real-time data, will demonstrate:• Was value realized by using an IWS? • How did the IWS completion, downhole choking, and monitoring contribute to adding value in accelerating hydrocarbon production, managing production allocations, delaying or minimizing water production, increasing recovery, and decreasing CAPEX or intervention costs?In conclusion, this paper will show how modeling technologies were developed to derive the IWS well and equipment design such as tool selection, customized choking positions, erosion protection, and tubing movement estimation. It will cover lessons learned through our experience in intelligent well systems, including flow modeling, erosion analysis, tool selection, and crossover control, and how we expect the future movement of this technology. to evolve. SPE 124916This paper will review several installations of various applications with intent to address these issues. First, defining the requirements of the well and the purpose within the field, an analysis of how much of the expectations was met with discussion on future usage of intelligent well technology. IWS Experiences and Value RealizationThe benefits of installing IWSs have been described by many authors 1-4 . In summary, those benefits can be attribubed to two main categories: for the purpose of reservoir management, including accelerate hydrocarbon production, improved reservoir knowledge, and flexible control production and drawdown to increase ultimate recovery; and for the purpose of decreasing OPEX or CAPEX cost, where decreasing intervention cost is one of the typical applications especially in offshore operation. The following paragaphs give the descriptions of those benefits, based on our IWS case histories, available production and well test data, operator feedback, and theoretical modeling analyses at pre-completion design or post-completion stages.A large percent of the planned IWS completions are used to control a well that penetrates multiple production zones with commingled production. Obviously, accelerate production, produce marginal reserves, improve reservoir knowledge, and increase recovery are the main drivers for these IWS applications. Two-Zone IWS Gas Producer and Planning of Completion -Manage commingled production, adding flexibility in reservoir managementCompletion description. Fig. 1 illustrates a schematic of one completed two-zone IWS well with a dual flow path frac-pack system. Two downhole control valves are installed. The lower downhole control valve is shrouded and connects to a small outer-diamet...

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Section: Two-zone Iws Auto-gas Lift and Planning Of Completion -Accelmentioning

confidence: 99%

“…Theoretic analyses were performed at this design stage to evaluate IWS completion, including downhole choking operation analyses, wellbore flow performance analyses, tool selection, and quick erosion analysis. For this purpose, a comprehensive thermal model technology has been developed [5][6][7] . Fig.…”

Section: Introductionmentioning

confidence: 99%

Intelligent Well Systems—Providing Value or Just Another Completion?

Sun

Constantine

Tirado

et al. 2009

SPE Annual Technical Conference and Exhibition

Self Cite

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An Application Case of Transferring Intelligent Well System Triple-Gauge Data into Real-Time Flow Allocation Results

et al. 2011

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Knowing the exact flow allocation for each controlled zone is important for well optimization and the management of an intelligent well system (IWS). For two-zone IWS producers, a broadly accepted downhole gauge configuration uses the triple-gauge system, where two gauges give the upstream side pressure/temperature (P/T) of the two downhole control valves, and one gauge gives the P/T inside tubing of the commingled fluid. Theoretically, this configuration gives the P/T boundary conditions between the two valves and the gauge carrier, where flow allocations can be solved numerically, based on the gauge readings and control valve settings. However, from what we have seen in the past 10 years of IWS applications, only a few have successfully published application cases regarding this topic. Is this an indication that a large number of two-zone triple-gauge IWS wells are operating in the low-confidence region of the two zone's production flow allocations? In this work, a comprehensive hydraulic model has been developed to address this topic. This paper will discuss a recent application of such a model to estimate the flow allocations of an existing two-zone deep-water IWS oil producer. The well began production in 2007. A total of 1,362 daily triple gauge data points are available for this study, where the monitored P/T data indicates that the well was flowed in multiphase conditions at downhole for a large percent of its production life. Verification was completed by comparing the predicted flow allocation results with this well's measured total rates and daily allocation rates. Further comparisons of the zonal allocations, between the model calculated results versus the zonal reservoir deliverability study predicted results, were also provided. These comparisons showed an excellent match between the predicted results, measured data, and the available reservoir study results. Descriptions of key factors to address the accuracy of the method have been provided, including compensated differential pressure, multiphase choke model, choke discharged coefficient, and fluid pressure-volume-temperature (PVT) behavior impact. A modified multiphase choke model was proposed in this study. The authors believe it will be more suitable for downhole valve operating and multiphase flow conditions. This case study has proven a very promising independent solution for continuous well rates estimation, with the solution based purely on choke pressure drops and intelligent well valve positions. The downhole monitoring P/T is normally based on seconds, which means that intelligent well flow allocations can be calculated in real-time without installing downhole venturi flow meters that may jeopardize well profitability and integrity. This solution brings measurable benefits for those IWS wells with no downhole flow meters, when taking into account the time and effort spent on periodic production tests, reservoir/well deliverability studies for production allocations, and potential production loss during the production tests.

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Transferring Intelligent-Well-System Triple-Gauge Data Into Real-Time Flow Allocation

Sun

Omole

Saputelli

et al. 2012

SPE Drilling &Amp; Completion

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Summary Knowing the exact flow allocation for each controlled zone is important for well optimization and the management of an intelligent well system (IWS). For two-zone IWS producers, a broadly accepted downhole gauge configuration uses the triple-gauge system, where two gauges give the upstream-side pressure/temperature (P/T) of the two downhole control valves and one gauge gives the P/T inside tubing of the commingled fluid [Baker Hughes IWS installation (2012) and Halliburton-WellDynamics IWS installation (2012) databases]. Theoretically, this configuration gives the P/T boundary conditions between the two valves and the gauge carrier, where flow allocations can be solved numerically, on the basis of the gauge readings and control-valve settings. However, from what we have seen in the past 10 years of IWS applications, only a few have published successful application cases regarding this topic. Is this an indication that a large number of two-zone triple-gauge IWS wells are operating in the low-confidence region of the two zone's production flow allocations? In this work, a comprehensive hydraulic model has been developed to address this topic. This paper will discuss a recent application of such a model to estimate the flow allocations of an existing two-zone deepwater IWS oil producer. The well began production in 2007. A total of 1,362 daily triple-gauge data points are available for this study, where the monitored P/T data indicate that the well was flowed in multiphase conditions at downhole for a large percentage of its production life. Verification was completed by comparing the predicted flow-allocation results with this well's measured total rates and daily-allocation rates. Further comparisons of the zonal allocations, between the model calculated results vs. the zonal-reservoir deliverability-study predicted results, were also provided. These comparisons showed a good match between the predicted results, measured data, and the available reservoir-study results. Descriptions of key factors to address the accuracy of the method have been provided, including compensated differential pressure, multiphase choke model, choke-discharge coefficient, and fluid pressure/volume/temperature (PVT) behavior impact. Sun's modified multiphase choke model was proposed in this study. The authors believe it will be more suitable for downhole valve operating and multiphase-flow conditions. This case study has proven a very promising independent solution for continuous well-rate estimation, with the solution based purely on choke-pressure drops and intelligent well-valve positions. The downhole monitoring P/T is normally based on seconds, which means that intelligent well-flow allocations can be calculated in real time without installing downhole venturi flowmeters that may add completion cost. In addition, a venturi flowmeter provides a smaller ID profile for the completion strings above/below it, which is inconvenient for future potential wellbore interventions. This solution brings measurable benefits for those IWS wells with no downhole flowmeters when taking into account the time and effort spent on periodic production tests, reservoir/well deliverability studies for production allocations, and potential production loss during the production tests.

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Interaction Between Intelligent Well Applications and Reservoir Management—A Comprehensive Thermal Modeling Technology for IWS Well

Cited by 4 publications

References 13 publications

Intelligent Well Systems—Providing Value or Just Another Completion?

Intelligent Well Systems—Providing Value or Just Another Completion?

An Application Case of Transferring Intelligent Well System Triple-Gauge Data into Real-Time Flow Allocation Results

Transferring Intelligent-Well-System Triple-Gauge Data Into Real-Time Flow Allocation

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