Combining Distributed Temperature Sensing With Inflow Control Devices Provides Improved Injection Profile With Real-Time Measurement in Power Water Injector Wells
- Drew E. Hembling (Saudi Aramco) | Sam Simonian (Shoaibi Group) | Garth John Naldrett (FloDynamic) | Garo Berberian (Saudi Aramco) | Mark Alexander Watson (Sensornet Ltd)
- Document ID
- Society of Petroleum Engineers
- SPE Intelligent Energy Conference and Exhibition, 23-25 March, Utrecht, The Netherlands
- Publication Date
- Document Type
- Conference Paper
- 2010. Society of Petroleum Engineers
- 5.6.11 Reservoir monitoring with permanent sensors, 4.1.2 Separation and Treating, 2.3.3 Flow Control Equipment, 1.6 Drilling Operations, 6.5.2 Water use, produced water discharge and disposal, 5.9.2 Geothermal Resources, 5.8.7 Carbonate Reservoir, 3.3 Well & Reservoir Surveillance and Monitoring, 4.4.2 SCADA, 5.1.1 Exploration, Development, Structural Geology, 3.3.1 Production Logging, 2 Well completion, 3.2.2 Downhole intervention and remediation (including wireline and coiled tubing)
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Passive ICDs (Inflow Control Devices) have been used in the past to enhance performance of producing horizontal wells in unfavorable environments such as non-uniform permeability and/or pressure variations along horizontal sections. This is the first ever attempt, to the best of our knowledge, at using ICDs combined with a fiber-optic DTS (Distributed Temperature Sensor) to manage the water injection profile across a horizontal reservoir horizon.
The cost of the permanent monitoring installation is comparable to a single coiled tubing deployed PLT intervention. This paper addresses how a passive ICD completion, utilizing DTS technology, was used to optimize and monitor well performance. In addition, the operational aspects of permanent vs. intervention monitoring are addressed while highlighting the opportunity for additional value creation using real-time monitoring combined with ICD technology.
This field trial demonstrates the effectiveness of the ICD system when used in an injection well for injection profiling and fluid diversion during acid stimulation. In addition, the DTS proved to be an effective alternative to production logging in this horizontal water injection well.
The key factor in the success of this project was the use of the 3-1/2?? ICD completion along with a DTS system to monitor and passively control the injection sweep across the entire reservoir section. DTS data were also obtained during pre-injection and acid stimulation operations. This was the first occasion in which an operator was able to evaluate stimulation efficiency of an ICD completion using permanent real-time monitoring methods.
To understand the injection profile and well performance, a DTS system was deployed with ICDs and Swellable Packers as a field trial for the planned injection well. Although previous systems have been run above the production packer, in cased multilateral wells, and in open hole ICD production wells1, 2, this was the first attempt worldwide to deploy a DTS system in an injection well with open hole completion across a passive ICD system. The objective of the field trial was to provide real-time information on multi-rate testing, indicate real time compartmental injection profiling, and eliminate the need for horizontal flow meter logging and well intervention.
The field trial considered in this paper utilized a nozzle type ICD design. The ICD acts as a restriction between the wellbore and annulus. The pressure drop across the ICD increases as a square of the flow rate, effectively preventing any one zone/ICD from providing a dominant outflow along the wellbore (See ICD equations on pg.13).
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