Horizontal Well Production Logging Deployment and Measurement Techniques for US Land Shale Hydrocarbon Plays

Heddleston, Duncan Craig

doi:10.2118/120591-ms

Cited by 25 publications

(7 citation statements)

References 1 publication

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“…For horizontal wells, the situation is different from the case of vertical or slanted wells because the geothermal temperature change is very small or zero sometimes. Many field cases (Brady et al, 1998;Chace et al, 2000;Foucault et al, 2004;Heddleston, 2009) showed temperature variations along the horizontal wells, and in order to explain this phenomenon, the subtle thermal effects in reservoirs and inside wellbore need to be considered in a temperature model for horizontal wells. In addition, the advancement of the DTS technology enables us to measure the temperature in the wellbore with the accuracy and resolution of approximately 0.1 ℃ (Ouyang and Belanger, 2006) (but they depends on the measurement acquisition time (Julian, 2007)).…”

Section: Temperature Modeling and Interpretationmentioning

confidence: 99%

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

Yoshida

Zhu

Hill

2014

SPE Production &Amp; Operations

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Fracture diagnostics is a key technology for well performance prediction of a horizontal well in a shale reservoir. The combination of multiple fracture diagnostic techniques gives reliable results, and temperature data has potential to provide more reliability on the results. In this work, we show an application of a temperature prediction model for a horizontal well with multiple hydraulic fractures in order to investigate the possibility of evaluating reservoir and hydraulic fracture parameters using temperature data. The model consists of wellbore model and reservoir model. Sensitivity studies were performed on temperature distribution to identify influential parameters out of the reservoir and hydraulic fracture parameters including reservoir porosity, reservoir permeability, fracture half-length, fracture height, fracture permeability, fracture porosity, fracture network parameters, and fracture interference between multiple clusters. In this work, in order to find contributions by a target fracture, temperature change sensitivity is evaluated. Single fracture case reveals that fracture permeability, network fracture parameters and fracture geometries are primary influential parameters on temperature change at the fracture location. And also, multiple fractures case shows that temperature change is augmented with the increase of fracture geometry and is decreased with the increase of fracture permeability. These results show the possibility of using temperature to determine these sensitive parameters, and also the

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Section: Temperature Modeling and Interpretationmentioning

confidence: 99%

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

Yoshida

Zhu

Hill

2014

SPE Production &Amp; Operations

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Section: Temperature Modeling and Interpretationmentioning

confidence: 99%

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

Yoshida

2013

SPE Annual Technical Conference and Exhibition

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Downhole temperature measurements either by permanent sensors or temporarily conveyed tools provide information that has been used in many production diagnosis applications. This paper presents a study that correlates the temperature behavior to the flow profile in a multi-stage fractured horizontal well. The ultimate goal is to interpret well performance and to optimize fracture treatment design from monitored temperature data. This study has developed flow and thermal models for horizontal wells with transverse fractures. The system was divided into a horizontal wellbore and a reservoir having multiple fractures in the study. The wellbore flow and thermal model were formulated based on mass, momentum and energy balance. Numerical reservoir simulation was adopted for the reservoir flow problem, and the reservoir thermal model was formulated by a transient energy balance equation considering viscous dissipation heating and temperature variation caused by fluid expansion besides heat conduction and convection. In the reservoir system, the primary hydraulic fractures perpendicular to the horizontal well were modeled with thin grid cells explicitly, and the fracture network around the horizontal well was modeled as an enhanced permeable zone with respect to the unstimulated matrix permeability. The reservoir grids between two fractures were logarithmically spaced to capture transient flow behavior. The reservoir flow and thermal model was coupled with the wellbore model to predict the temperature distribution in a horizontal wellbore. The results of the model show two main mechanisms in this thermal problem: heat conduction by formation heating/cooling effects at non-perforated zones, and wellbore fluid mixing effects with reservoir inflow at fracture locations (fluid entry points). The examples in the paper illustrated that the models can be used to predict temperature profiles in stimulated horizontal wells for identical or non-identical transverse fractures. Sensitivity studies were performed to evaluate the influences of fracture conductivity and half-length on temperature behavior in the defined system. The results indicate that the wellbore temperature is primarily sensitive to fracture geometry (fracture half-length). It is possible to interpret the fracture geometry using temperature data after the flow rate is stabilized after certain period of production. In addition, wellbore temperature is also sensitive to fracture conductivity. However, the signal of high fracture conductivity diminishes, and after the surface flow is stabilized, the signal might not be identified by temperature measurement. Real time temperature data measurement is helpful for the evaluation of fracture conductivity.

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“…The Temperature measurement is ideal for correlating to the changes in the holdup as water is usually a warmer event and gas (due to Joule Thompson expansion) is a cooler event. (D. Heddleston, 2009) In a high gas/liquid ratio flow in horizontal wells, the wellbore gas/liquid holdup can be ~ 70% 99%. Therefore, using a bulk flowrate measurement is the most practical & reliable method to measure velocity as seen in Figure 4, demonstrating repeatable / consistent velocity passes is shown.…”

Section: Horizontal Production Loggingmentioning

confidence: 99%

“…The horizontal laterals can intersect these existing natural fractures or faults in the formation which lead to unproductive intervals across the lateral. (D. Heddleston, 2009) In some areas the completion and stimulation of a shale horizontal well can be close to 60% of the total well cost; therefore, operators are experimenting with lower cost stimulation techniques to utilize less resources in the hope of creating efficient production.…”

Section: Introductionmentioning

confidence: 99%

Shale Gas Horizontal Production Logging Measurements and Challenges

Heddleston¹,

Haggerty²

2010

Tight Gas Completions Conference

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Traditional shale formations are presently being produced via horizontal well completions. These horizontal wells consist of numerous selectively stimulated stages containing as many as 20 stages spread out across 2000 ft to 9000 ft interval.The well completions have been stimulated using low technology methods such as high volume water / slick water & sand. The initial production of the well requires a short period of flowback of the injected load water prior to the wells being kicked off with hydrocarbon production. The load water flowback can range from as little as 2% load return as high as 70% returns. Since these types of formations are far from being homogeneous, these horizontal laterals can intersect existing natural fractures or faults in the formation or an aggressive stimulation could induce fractures into existing natural fracture or faulting network. This paper will showcase horizontal well production logging measurements ideal for this flowing environment in order to deliver a high confidence, representative flow profile. In addition, deployment techniques & the logging challenges will be discussed to establish the best possible representative flowing environment for measuring these types of well completions.

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Horizontal Well Production Logging Deployment and Measurement Techniques for US Land Shale Hydrocarbon Plays

Cited by 25 publications

References 1 publication

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

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

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

Shale Gas Horizontal Production Logging Measurements and Challenges

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