World's First Production Logging with Fiber-Optic-Enabled Coiled Tubing (CT)

Noya, Jose Vidal; Adil, Abdur Rahman; Wolf, Kellen; Chee, Soon Seong; Stuker, John; Rodriguez, F. L.

doi:10.2118/142443-ms

Cited by 5 publications

References 5 publications

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Fiber-Optic Technology Allows Real-Time Production Logging Well Campaign To Continue Where Traditional Logging Tools Fell Short

et al. 2012

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Exploration and exploitation of the shale formations in the United States has continued to accelerate since the early 2000's. Once considered to exist only as a cap rock, shale is now proving to be one of the most important reservoir rocks in North America and throughout the world. The demand for production logging (PL) in these reservoirs has increased due to the desire to better understand the basis behind higher stimulation efficiency and increased production results. Data collected via production logs can be used to evaluate efforts to enhance production through better zonal targeting, modifications to completion/hydraulic fracture design and/or alternate zonal isolation procedures. Drilling extended reach horizontal wells has allowed for more efficient exploitation of these formations but has also increased the number of potential obstacles to overcome in order to obtain complete and accurate production logs. Some of these obstacles include: severe doglegs which interfere with logging tool bending capability, substantial wellbore debris and/or added friction surface contact impacting depth of data capture, and completion configurations that limit equipment options and ease of logging. This paper will identify these critical factors and address proper candidate well selection and job preparation. It will also illustrate a multi-well logging campaign in the Marcellus shale, which highlights the benefits of fiber optic technology as a suitable alternative to traditional production logging techniques. .

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Fiber-Optic Technology Allows Real-Time Production Logging Well Campaign To Continue Where Traditional Logging Tools Fell Short

et al. 2012

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Pushing the Limits of Distributed Temperature Survey Analysis in Mega-Reach Power Water Injectors

Al-dhufairi

Al-Yateem

Duthie

et al. 2014

Abu Dhabi International Petroleum Exhibition and Conference

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Increases in well complexity and stimulation challenges have led to more complicated stimulations. The challenge that consistently arises after conceptually designing the treatment is how to determine the zonal coverage and evaluate the stimulation, especially in extended reach wells in carbonate reservoirs. Significant effort has been spent on using modern technologies to qualitatively evaluate zonal coverage and estimate the skin factor evolvement after the treatment. No work has yet answered the following question: How does matrix acidizing alter near-wellbore permeability and affect the zonation of the wellbore when treating carbonate reservoirs?In long horizontal wells that are drilled in carbonate formations, it is believed that wormholing significantly alters the near-wellbore apparent permeability. Nevertheless, methods to estimate the change in permeability resulting from a matrix treatment are not known, and usually the change is accounted for in simulators by assigning a very low skin value. Other work conducted in carbonate reservoirs using pressure transient analysis (PTA) techniques has shown that applying a change in permeability is necessary to obtain a type-curve match.This paper presents an innovative workflow and algorithm to estimate the changes in the critical matrix rock properties and how to incorporate these changes into further simulation. The algorithm integrates the while drilling mobility data, open hole porosity logs, pressure transient data, distributed temperature survey data, and production logging data to verify the accuracy of the model by using the flow rate as the control parameter for iterations.A case study shows how we could derive a flow profile for the pre-stimulation stage, optimize matrix stimulation treatments in real time according to the formation response and diversion efficiency, define reservoir zones that are contributing to flow before and after the treatment, and finally, estimate new values of permeability and skin to be utilized in post-treatment reservoir simulations.

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Optimizing Well Evaluation: Real Time Monitoring Using Fiber Optic Conveyed in Coiled Tubing and N2 Lifting

Villanueva

Burgos

Humbert

et al. 2015

SPE Latin American and Caribbean Petroleum Engineering Conference

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Well evaluation is the primary method used in the oilfield to determine the true well's production potential and reservoir characteristics. During a well evaluation, downhole parameters are commonly registered using downhole memory gauges, which can only be retrieved and read after the evaluation have finished. The problem with this conventional method is the uncertainty or ambiguity results and the inaccurate data of the downhole parameters; which often lead to inefficient tests times and difficulties for well test interpretation.The use of Fiber Optic for Real-time downhole measurements conveyed on Coiled Tubing (CT) and Nitrogen (N2) Lifting provide a unique live insight that allow us to monitor the well response while production or evaluation is performed, eliminating the uncertainties that surrounds traditional methods. Nitrogen lifting with Coiled Tubing was introduced as an alternative evaluation method for the common Hydraulic Jet Pumping that proved advantages accelerating well response and increasing the accurate of the reservoir data for well evaluation and artificial lift design nevertheless this still faces the delayed on the pressure data and transient interpretation. Implementing the Real Time downhole measures (P, T) is possible to eliminate uncertainties of reservoir parameters that surround well evaluations, adjust job parameters on-site, optimize job resources and time and finally anticipate artificial lifting design. This paper will present the results of the implementation of this new method in the area for well evaluation allowing real-time measurements of down hole pressure/temperature. Combining the fluid lifting with N2 through the CT, reservoir response is continuously monitored; thereby, allowing in advance an adequate design of the lifting system reducing nonproductive time. Real-time measurements and accurately data of the reservoir allow defining if a further stimulation treatment is needed. Actual treatment program can be continuously monitored or modified, to achieve optimal results. The first trial using the system demonstrated that the application can be used with a high degree of accuracy and control for the parameters and treatment designs that are not achievable using conventional techniques as the Hydraulic Jet pumping, gauges conveyed in slick line, joined tubing and/or using surface data to predict downhole behavior.

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World's First Production Logging with Fiber-Optic-Enabled Coiled Tubing (CT)

Cited by 5 publications

References 5 publications

Fiber-Optic Technology Allows Real-Time Production Logging Well Campaign To Continue Where Traditional Logging Tools Fell Short

Fiber-Optic Technology Allows Real-Time Production Logging Well Campaign To Continue Where Traditional Logging Tools Fell Short

Pushing the Limits of Distributed Temperature Survey Analysis in Mega-Reach Power Water Injectors

Optimizing Well Evaluation: Real Time Monitoring Using Fiber Optic Conveyed in Coiled Tubing and N2 Lifting

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