Real-Time Diversion Quantification and Optimization Using DTS

Glasbergen, Gerard; Gualtieri, Dan; Trehan, Rakesh; Domelen, Mary Susan Van; Nelson, Micky

doi:10.2118/110707-ms

Cited by 18 publications

(3 citation statements)

References 16 publications

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“…The latter phenomenon was observed earlier and described in a foam-diversion case history with ball sealers (Glasbergen et al 2007). Therefore, surface treating pressure is questionable not only in high-rate fracture applications, but also as a reliable indication of diversion.…”

Section: Traditional Measurement Techniquessupporting

confidence: 67%

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Fluid-Diversion Monitoring: The Key to Treatment Optimization

Glasbergen

Yeager

Reyes

et al. 2010

SPE Production &Amp; Operations

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In stimulation and injection treatments for removing or preventing formation damage, placement of the injected fluids is essential. Throughout the years, several diversion and placement techniques have been applied to obtain a desired fluid placement. A recent development is the application of distributed temperature sensing (DTS) to monitor the temperature profiles along the wellbore in real time during these treatments. Recent case histories showed that fluid placement can be quantified. Quantification of fluid distribution enables one to determine the flow distribution both before and after a diverter stage so that the diversion effect can be quantified.This paper discusses several case histories where DTS was applied to quantify the effectiveness of different diverters. The effects of chemical diverters, such as relative permeability modifiers (RPMs) and in-situ-crosslinked acids (ICAs), and moretraditional diverters, such as rock salt, are discussed. Because of the advanced monitoring used with the temperature profiles, both the immediate and the sustained effect of the diverters can be measured. The changes in the flow distribution are not limited to diverters. Reactive fluid or changes in flow rate can change the flow distribution as well. These effects were measured during the stimulation treatments.The post-treatment analysis of the measured temperature profiles in combination with treatment pressures and flow-rate information resulted in accurate knowledge of the effectiveness of the different diverters and stimulation effects over time. This knowledge will be used in future treatments to help optimize volumes, rates, fluid systems, and the selection of the appropriate diverter.

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Section: Traditional Measurement Techniquessupporting

confidence: 67%

“…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).…”

Section: Diversion Monitoring Using Dtsmentioning

confidence: 99%

Fluid-Diversion Monitoring: The Key to Treatment Optimization

Glasbergen

Yeager

Reyes

et al. 2010

SPE Production &Amp; Operations

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“…When fluids containing the particulate material are pumped, they will enter high-permeability or undamaged zones, causing the buildup of a low-permeability particle pack within the perforation tunnel or a filter cake on the formation face. The added pressure drop caused by the particles increases flow resistance to the areas where the diverting agent has been deposited, causing diversion of flow to other parts of the interval where little or no diverting agent has been placed (Glasbergen et al 2006(Glasbergen et al , 2007. There are several polymeric materials that are gradually degraded by water through a process known as hydrolysis.…”

Section: Introductionmentioning

confidence: 99%

Field-Proven Effectiveness of Self-degrading Diversion Particulates as a Diversion Method in High- and Ultra-Low-Permeability Formations

Gutierrez

Araujo

Medina

2015

SPE Production and Operations Symposium

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The optimization of stimulation treatments in Mexico has required the use of novel diversion technologies to increase the productivity of wells by improving the coverage of stimulation fluids and reducing completion costs. Self-degrading particulate has become widely used in the country because of the diverter flexibility. Job experiences range from hydraulically fracturing unconventional reservoirs to the matrix acidizing of naturally fractured carbonate formations. The purpose of this paper is to verify the effectiveness of this material for achieving the selective stimulation of multiple intervals, either in horizontal or vertical wells.Because there is no confidence in a complete stimulation of all open intervals, diagnostic techniques have been implemented to determine the effectiveness of diversions. For near-wellbore (NWB) monitoring, technologies such as radioactive tracers and distributed temperature sensing (DTS) have been used to determine treatment fluid locations after the application or in real-time. Downhole microseismic monitoring has been performed for far-field indications of diversion success in hydraulic fractures of vertical wells with multiple intervals open at the same time. This paper discusses four wells from the north, central, and south regions in Mexico. All of them have completely different reservoir properties and completion types.Improved production increase was the main difference between wells where diversion with selfdegrading particulate diverters was used compared to those that were not treated with diverters; a production increase from 30 to 70% was achieved. Completion time was reduced with the implementation of the novel self-degrading particulates vs. other possible methods, allowing faster return of investment (ROI). Real-time decision making could be performed using both a diverter and monitoring techniques to assure a uniform treatment placement. Another differentiator was the simple logistics required to handle the material compared to other additives employed in the past. Because of the performance of the diverter, it has been applied in more reservoirs with extremely variable permeabilities across the country (tight gas and oil sandstones, gas and oil shales, and naturally fractured oil-bearing carbonates).Downhole temperature is the main controlling factor to accelerate or retard the degradation of the particulate, as it must take into account that in cooler formations, longer times are required to achieve complete degradation. Its independence of the wellbore geometry has increased the implementation in openhole and cased-hole completions, despite the final shape of the perforations.

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DTS Monitoring of Hydraulic Fracturing: Experiences and Lessons Learned

Sierra

Kaura

Gualtieri

et al. 2008

SPE Annual Technical Conference and Exhibition

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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.

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Real-Time Diversion Quantification and Optimization Using DTS

Cited by 18 publications

References 16 publications

Fluid-Diversion Monitoring: The Key to Treatment Optimization

Fluid-Diversion Monitoring: The Key to Treatment Optimization

Field-Proven Effectiveness of Self-degrading Diversion Particulates as a Diversion Method in High- and Ultra-Low-Permeability Formations

DTS Monitoring of Hydraulic Fracturing: Experiences and Lessons Learned

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