Schlumberger Technology Corporation

Andrew Carnegie

Oliver Clinton Mullins

Kai Hsu

Peter S Hegeman

Chengli Dong

Ricardo Vasques

Edward Harrigan

Henri-Pierre Valero

Lalitha Venkataramanan

Bhavani Raghuraman

Andrew L Kurkjian

Go Fujisawa

Michael O'Keefe

Fikri Kuchuk

ChengGang Xian

Mustafa Onur

Nicolas Adur

James J Dunlap

Matheus Nogueira

Alejandro Duran

Serkan Yilmaz

Jichao Chen

Methods and systems are provided for downhole analysis of formation fluids by deriving fluid properties and associated uncertainty in the predicted fluid properties based on downhole data, and generating answer products of interest based on differences in the fluid properties. Measured data are used to compute levels of contamination in downhole fluids using an oil-base mud contamination monitoring (OCM) algorithm. Fluid properties are predicted for the fluids and uncertainties in predicted fluid properties are derived. A statistical framework is provided for comparing the fluids to generate, in real-time, robust answer products relating to the formation fluids and reservoirs thereof. Systematic errors in measured data are reduced or eliminated by preferred sampling procedures.

System and methods of deriving fluid properties of downhole fluids and uncertainty thereof

A technique is described for interpretation of IPTT tests. In one implementation, the technique may be configured or designed to standardize the complete interpretation procedure of IPTT in a heterogeneous reservoir, using if available, modern wireline logs (such as, for example, nuclear magnetic resonance and imaging), dynamic data from wireline formation testers and/or any other relevant information (such as, for example, geological description, core data and local knowledge) as constraints on the interpretation. Additionally, an iterative method may be used to define formation layering. An advanced regression technology may also be used to obtain optimized horizontal and vertical permeabilities of reservoir layers. Further a graphical user interface (GUI) based IPTT workflow technique of the present invention provides an integrated user-friendly interpretation platform for analyzing formation testing pressures and flow rate measurements in order to estimate the values and associated uncertainties of local characteristics of a hydrocarbon reservoir such as, for example, local permeability, local reservoir pressure, local compressibility, etc.

System and methods of characterizing a hydrocarbon reservoir

A method and apparatus for sampling formation fluid includes drawing formation fluid from the subterranean formation into the downhole tool and collecting the formation fluid in a sample chamber. An exit flow line is operatively connected to the sample chamber for selectively removing a contaminated and/or clean portion of the formation fluid from the sample chamber whereby contamination is removed from the sample chamber. For example, a clean portion of the formation fluid may be passed to another sample chamber for collection, or a contaminated portion may be dumped into the borehole.

Downhole sampling apparatus and method for using same

A method for refining fluid sample data includes obtaining optical density data for a fluid sample in at least two color channels and at least one fluid component channel and determining a color-absorption function from the optical density data for the fluid sample in the at least two color channels. The method also includes calculating a portion of the optical density caused by color absorptions in each of the at least one fluid component channels, and de-coloring the optical density data in each of the at least one fluid component channels by removing the portion of the optical density data caused by color absorption.

Optical fluid analysis signal refinement

A method of sampling reservoir fluid includes establishing communication between a reservoir and an entry port of a flow line disposed in a borehole penetrating the reservoir. The method includes separating fluid received in the entry port into individual fluid components and sequentially flowing slugs of each individual fluid component along the flow line, observing the slugs as they move along the flow line in order to determine the composition of the slugs, estimating when a desired slug containing a desired fluid component would be in the vicinity of a sample chamber in the flow line, and opening the sample chamber to capture the desired slug when the desired slug is in the vicinity of the sample chamber. The method also includes checking that the sample chambers open and close successfully. Finally, the method further includes creating an accurate record of events, which can then be used to audit the sampling process.

Real-time monitoring and control of reservoir fluid sample capture

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Abu Dhabi, United Arab Emirates

Andrew Carnegie