DTS Monitoring of Hydraulic Fracturing: Experiences and Lessons Learned

Abstract

Real-time monitoring of hydraulic fracturing using fiber optic distributed temperature sensing (DTS) is starting to be used to estimate fracture initiation depth, vertical coverage and number of generated fractures, effects of diverting agents, and undesired flow behind casing. DTS monitoring of flowback and production can also help to assess the effectiveness of the stimulation treatment. To successfully achieve the monitoring objectives, aspects such as fiber deployment, fiber integrity at high injection rates, location and thermal coupling of fiber with respect to flow path, frequency of data acquisition and resolution, and real-time visualization and modeling need to be carefully considered. This paper presents experiences in the analysis of transient DTS data acquired during high-rate, multi-stage hydraulic fracturing in vertical, deviated, and horizontal oil and gas wells. The location of fiber, conveyed with coiled tubing inside the flow path or cemented behind casing, has a major impact in the temperature response, depending of the thermal conductivity between the fiber cable and the injected fluid path. When the fiber is hung inside casing, the fluid distribution can be challenging, especially if the deepest fluid leak is closer to the bottom of the treated interval, because the temperature along the fiber very quickly becomes equal to the fluid temperature with a minimum gradient straight-line pattern due to high fluid rate and velocity. To overcome this condition the use of induced hot/cold thermal tracers together with temperature modeling has been introduced, allowing the calculation of fluid rate distribution along the perforated intervals. Where the fiber is cemented behind casing, well defined patterns, based on the temperature value, can be recognized to discriminate between flow inside and behind casing, allowing out-of-zone fracture assessment. The thermal coupling of the fracturing fluid inside the casing and the fiber can be very weak at certain levels where small gas "insulation" pockets occur around the fiber, keeping the fiber temperature closer to the geothermal than fluid temperature. At clamp depths or well cemented zones, fiber temperature is much closer to fluid temperature, because the thermal coupling is strong at these levels. When the fracturing fluid flows behind casing, due to bad cement isolation, reaches the fiber cable, the temperature becomes essentially equal to fluid temperature. The advantages and limitations of both cases are discussed based on the type of well, length of gross pay, fracture design, treatment rate, and type of fluids.

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

“…A major limitation of this method is that these measurement can provide only what happens to the fracture at the wellbore, and it does not provide any information about the fracture when it is father than about 1 to 2 ft from the wellbore (Cipolla and Wright, 2002). Radioactive tracer and production logging techniques are grouped into this method, and recently, the application of the DTS and distributed acoustic sensing technology is examined for the fracture diagnostics in both of quantitative and qualitative analysis (Hoang et al, 2012;Huckabee, 2009;Molenaar et al, 2012;Sierra et al, 2008;Tabatabaei and Zhu, 2012).…”

“…Glasbergen et al (2009) presented the real time quantification of fluid distribution during a matrix treatment using DTS data for better understanding of the stimulation. Sierra et al (2008) and Huckabee (2009) applied the DTS data to diagnose the fracture stimulation and evaluate well performance. For shale reservoirs, Gonzalez and Chokshi (2012) presented the DTS application, and recently the DTS technology is used with distributed acoustic sensing techniques for fracture diagnostics in shale reservoirs (Molenaar et al, 2012).…”

Fluid-Diversion Monitoring: The Key to Treatment Optimization

“…Thus, the created velocity profile can be transformed relatively easily to a leakoff profile. This quantitative analysis is described in detail in the literature (Glasbergen et al 2009;Glasbergen et al 2007;Sierra et al 2008).…”

Importance of Downhole Measurements, Visualization and Analysis in Producing Unconventional Wells

“…While downhole measurement systems are being deployed in unconventional wells, their only objective has been towards understanding the reservoir response to either the fracturing process in shale or the steam chamber creation in SAGD [1][2][3][4][5][6][7][8][9] . In the authors' opinion, very little use is made or objectives are set for these systems towards continuous production management.…”