Monitoring Inflow Distribution in Multi-zone, Velocity String Gas Wells Using Slickline Deployed Fiber Optic Distributed Temperature Measurements

Abstract

Fiber-optic systems are able to generate a temperature log along an optical fiber using a laser source and analysis of the backscattered light. This paper details a novel application of this technology using an optic fiber embedded in a 1/8 th inch slickline cable to calculate the inflow distribution of multi-zone gas wells with velocity strings.EnCana's multi-zone gas wells in the Deep Basin of Western Canada are often completed with production tubing landed near the lowest perforated interval to act as a velocity string and lift produced water to surface. This completion technique makes spinner production logs impossible to run without initially performing a wellsite operation to lift the tubing shoe above the reservoir, requiring either a workover rig or a snubbing unit. Running a slickline containing an optical fiber to the bottom of the tubing and producing the well up the annulus for a short period allows the temperature profile of the well to be measured and therefore, the inflow distribution of the well can be calculated.Determining the inflow distribution of multi-zone gas wells now becomes a simple slickline operation with no tubing shift required. Additional benefits are the detection of crossflow on shut-in and the measurement of flowing bottomhole pressure when a gauge is run at the end of the slickline. The process is cost effective, less risky than conventional production logging, and the slickline can be safely employed where there is significant surface pressure.The paper uses case studies validated by spinner log comparisons to demonstrate that slickline fiber optic distributed temperature sensor measurements are a viable method for performing reservoir surveillance in multi-zone gas wells with velocity strings in Western Canada. Utilizing fiber optic measurements in these wells reduces operating costs and should ultimately lead to increased efficiency of reservoir stimulation practices.

Approach to shape factor determination in estimating horizontal wells productivity for pressure transient model of Mutalik et al.

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Temperature Prediction Model for a Horizontal Well with Multiple Fractures in a Shale Reservoir

“…Fryer et al (2005) applied it for the real time temperature measurement in multi-layered reservoir to identify zone production rate changes. Johnson et al (2006) and Huebsch et al (2008) presented a successful application for gas flow rate profiling using the measured DTS data of vertical wells.…”

Determining multilayer formation properties from transient temperature and pressure measurements in gas wells with commingled zones

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