This paper describes how distributed temperature sensing (DTS) based on Raman Scattering is being used as an in-situ logging technique in oil & gas wells. Traditional methods of gathering production data to characterize oil & gas well performance have relied on the introduction of electric logging tools into the well. This can be an expensive process in highly deviated or horizontal wells and usually results in the well being shut-in with the loss or deferment of hydrocarbon production. More recently permanently placed pressure sensors based on CMOS technology have been used, but these systems do not easily deliver distributed measurements and reliability has been found to be poor.In order to apply DTS technology to this new type of application a number of new processes and methods have been developed. These include improved optical fiber coatings for high temperature applications, adaptation of fiber-blowing techniques techniques pioneered by the telecoms industry for installation and advanced interpretation techniques that allow distributed temperature profiles in the oil & gas well to give valuable information about flowing profiles, fluid properties and the condition of artificial lift equipment that is used to enhance production.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractUnwanted water production has long been one of the biggest problems that the oil and gas industry has had to address in efficiently producing hydrocarbons. This paper describes how fiber-optic-distributed temperature sensing (DTS) has been used in conjunction with remotely operated hydraulic interval control valves (ICVs) as an economical management tool for controlling water encroachment. Used with intelligent well technology, this method provides interventionless control and selectivity of producing intervals using surface-actuated hydraulic ICVs so that unwanted water production can be managed more effectively to maximize oil recovery. Distributed temperature measurements at one-meter intervals in the wellbore provide data that assists in the determinations of zonal contribution and the identification in the change of fluid properties or water ingress.This method was installed on the Douglas Platform in Liverpool Bay, United Kingdom. The completion was comprised of an ESP pump, hydraulic on/off disconnect, retrievable packers with hydraulic feed throughs and hydraulic ICVs. An optical fiber that acquires continuous distributed temperature data is installed into one of the hydraulic control lines that operate the hydraulic ICVs. Opto-electronic instrumentation on the platform allows distributed temperature data to be transmitted in real-time to a shore-based asset team.The combination of fiber optics and hydraulic interval control valves provides a number of benefits:• The number of penetrations through tubing hangers and packers are reduced if required• The fiber optic sensor is capable of gathering realtime logging data from multiple intervals without intervention • The ICVs provide interventionless zonal control • The disconnect system facilitates ESP workover and recompletion.
An example of how fine scale heterogeneity was incorporated into a large full-field model is presented. A detailed geologic description was prepared and implemented in a 2D crosssectional model. The important heterogeneities in this reservoir were found to be shale barriers. A simple Markov method for modeling fine scale shales was developed. Stone's method for determining interblock relative permeabilites }Vas superior to Kyte and Berry's method, in this case.
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