DTS Sensing: An Emerging Technology Offers Fluid Placement for Acid

Reyes, Robert P.; Yeager, Valerie Jean; Glasbergen, Gerard; Parrish, Joseph; Tucker, R. C.

doi:10.2118/145055-ms

Cited by 5 publications

(2 citation statements)

References 23 publications

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“…Major fluid-loss zones can often be identified during shut-in periods (Reyes et al 2011); however, crossflow masked this warmback information is this instance. Seawater was injected during initial DTS cable deployment to reduce friction and maximize survey reach.…”

Section: Dts Data Gathering and Interpretationmentioning

confidence: 99%

Interwell Communication as a Means to Detect a Thief Zone Using DTS in a Danish Offshore Well

et al. 2013

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Controlled acid jetting (CAJ) was developed for relatively thin but aerially extensive oil accumulations in low-permeability chalk formations. These relatively low-cost long horizontal wells enabled the waterflood development of a number of Danish offshore fields. On initial completion of the CAJ wells, large volumes of acid were bullheaded to remove the mud cake from the horizontal reservoir section. For the distribution of acid, approximately 4-to 5-mm CAJ holes were predrilled in the uncemented liner. However, in a number of the injector-producer patterns, short-circuiting of water was observed. In some cases, this was interpreted to have been exacerbated by the large-volume acid stimulations. Detection of the location of the thief zones is not straightforward in CAJ wells because of the restricted hydraulic communication through the CAJ holes.This work presents interwell communication as a means to detect the location of thief zones in a CAJ well using distributed temperature sensing (DTS) technology along with a production logging tool (PLT) and water flow log (WFL) for the first time. The thief zones were located by alternatively producing and shutting-in a neighboring well (Well A2) and recording the temperature data in the injector well (Well A1). When the producer well was flowing, the temperature in the injector well stabilized during the shut-in period, instead of warming back at a constant rate. The temperature data from DTS collected during injection and shut-in conditions in the injector well was used along with the PLT and WFL logs to determine the location of the main thief zone at 9,278 ft. Another temperature anomaly in DTS data occurring at approximately 11,200 ft suggested the presence of a minor thief zone, potentially communicating with a third neighboring well (Well A3). A thermohydraulic mathematical model, which was developed as part of this work to simulate the bidirectional fluid flow through the liner and annulus assembly, was used to determine the temperature signatures associated with thief zones in a CAJ well. It was discovered that a change in slope in the fluid temperature profile occurred at the thief zone when fluid was injected. Similar features were detected in the temperature profile obtained from the DTS log in the injection well. Hence, the model predictions concurred with the observations from the field.

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Section: Dts Data Gathering and Interpretationmentioning

confidence: 99%

Interwell Communication as a Means to Detect a Thief Zone Using DTS in a Danish Offshore Well

et al. 2013

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“…The temperature-profile data can be transformed into flow information only when an accurate value of the JTC of reservoir gas at the bottomhole conditions is available (Wang et al 2008). This flow information can be used during stimulation jobs, such as acidizing, to monitor the flow of acid into different zones (Clanton et al 2006;Reyes et al 2011;Tan et al 2011;Villesca et al 2011), as well as for applications such as the determination and quantification of water breakout in wells (Yoshioka et al 2007). Knowledge of the JTC can also aid in predicting temperature profiles in high-pressure/high-temperature wells (Baker and Price 1990) and geothermal wells (Golub et al 2004), as well as in temperature logs (Steffensen and Smith 1973) and well-test interpretations (Bahrami and Siavoshi 2007).…”

Section: Introductionmentioning

confidence: 99%

A Simple and Reliable Approach for the Estimation of the Joule-Thomson Coefficient of Reservoir Gas at Bottomhole Conditions

2013

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With the advent of distributed temperature sensing (DTS), accurate and continuous monitoring of the wellbore-temperature profile is possible, which helps identify fluid flow from each reservoir layer. The reliable prediction of fluid flow during large drawdown requires an accurate value of the Joule-Thomson coefficient (JTC), which is a measure of the change in temperature (T) of a fluid for a given change in pressure (P) at constant enthalpy. The JTC also serves as an input for the interpretation of temperaturelog data, which can be used to identify water-or gas-entry locations. Furthermore, an accurate JTC value is important when modeling the thermal response of the reservoir.The equation-of-state (EOS) method can be used to predict the JTC of reservoir gas. However, this might not be an easy task because of the complexity involved. In contrast, a simple and reliable method to evaluate the JTC for reservoir gas is presented. Conditions under which this method is applicable are discussed in detail by referring to a typical phase diagram. In addition, a discretized approach to calculate the temperature change during a throttling process with the JTC is also presented.The methodology has been validated at three levels with experimental data available in the literature-comparison of experimental vs. predicted JTC values of mixtures, comparison of experimentally observed vs. predicted temperature drop for a given pressure drop with laboratory-scale data, and comparison of experimentally observed vs. predicted temperature drop for a given drawdown with actual reservoir data. A good match with experimental data was obtained within all three areas, demonstrating the reliability of the methodology.

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A Simple and Reliable Approach for Estimation of Joule-Thomson Coefficient of Reservoir Gas at Bottomhole Conditions

2012

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With the advent of distributed temperature sensing (DTS), accurate and continuous monitoring of the wellbore temperature profile is possible, which helps identify fluid flow from each reservoir layer. Reliable prediction of fluid flow during large drawdown requires an accurate value of the Joule-Thomson coefficient (JTC), which is a measure of the change in temperature of a fluid for a given change in pressure at constant enthalpy. The JTC also serves as an input for interpretation of temperature log data, which can be used to identify water or gas entry locations. Furthermore, an accurate JTC value is important when modeling the thermal response of the reservoir. The equation-of-state (EOS) method can be used to predict the JTC of reservoir gas. However, this might not be an easy task because of the complexity involved. In contrast, a simple and reliable method to evaluate the JTC for reservoir gas is presented. Conditions under which this method is applicable are discussed in detail by referring to a typical phase diagram. In addition, a discretized approach to calculate the temperature change during a throttling process using the JTC is also presented. The methodology has been validated at three levels using experimental data available in the literature—comparison of experimental vs. predicted JTC values of mixtures, comparison of experimentally observed vs. predicted temperature drop for a given pressure drop using lab-scale data, and comparison of experimentally observed vs. predicted temperature drop for a given drawdown using actual reservoir data. A good match with experimental data was obtained within all three areas, demonstrating the reliability of the methodology.

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DTS Sensing: An Emerging Technology Offers Fluid Placement for Acid

Cited by 5 publications

References 23 publications

Interwell Communication as a Means to Detect a Thief Zone Using DTS in a Danish Offshore Well

Interwell Communication as a Means to Detect a Thief Zone Using DTS in a Danish Offshore Well

A Simple and Reliable Approach for the Estimation of the Joule-Thomson Coefficient of Reservoir Gas at Bottomhole Conditions

A Simple and Reliable Approach for Estimation of Joule-Thomson Coefficient of Reservoir Gas at Bottomhole Conditions

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