Schlumberger Technology Corporation

Other

Cameron International Corporation

Illinois Institute of Technology

Schlumberger Technology Center

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Terizhandur S Ramakrishnan

Nikita Chugunov

Hua Zhang

Fikri John Kuchuk

Quincy K Elias

Yusuf Bilgin Altundas

Wenlin Zhang

Albert Perez

Tarek M Habashy

Raghu Ramamoorthy

Sandeep Verma

Li Jiang

Cosan Ayan

Andrew John Carnegie

Michael G Supp

Thomas J Neville

Jiyao Li

Bhavani Raghuraman

Raj Kumar Michael Thambynayagam

John Tombari

Albert Perez, Jr

Roy Koveleski

Gary Martin Oddie

William John Bailey

Min-Yi Chen

Soraya Sofia Betancourt

Peter Gerhard Tilke

William E Kenyon

Peter Allan Goode

Anthony Goodwin

Muthusamy Vembusubramanian

David J Wilkinson

Fikri Kuchuk

Badarinadh Vissapragada

Sukru Sarac

Romain De Loubens

Edmund J Fordham

Andrew John Duguid

Albert M Perez

Philippe Lacour-Gayet

Jaisree Iyer

Charles S Oakes

Joseph Walter

Rod Nelson

Sam Smonian

Raji Shankar

Oliver Clinton Mullins

Julian J Pop

Edward Harrigan

Kenneth Edward Stephenson

Lalitha Venkataramanan

Francois M Auzerais

John Mervyn Cook

Stephane Vannuffelen

Eric P Donzier

Benoit Couet

Lawrence James Leising

Charles Flaum

Go Fujisawa

Kashif Rashid

Ian D Bryant

Thomas H Zimmerman

Paul Simon Hammond

David J Rossi

Joseph Ayoub

Nicholas N Bennett

Timothy G J Jones

Chaur-Jian Hsu

David Furse Allen

Bertrand Du Castel

Stuart I Jardine

Lang Zhan

Jose Navarro

Ram Sunder Kalyanaraman

Mark Flaum

Brindesh Dhruva

Ashok Belani

Darsh T Wasan

Naoki Saito

Kirsty Morton

Hani Elshahawi

Robert Kevin O'Leary

Richa Sharma

Valery Polyakov

Lawrence M Schwartz

Eric Leon Stabinski

Francois B Fayard

Syed Tariq

Pierre Barrat-Charlaix

Alpaslan Z Tengirsek

Ashok K Belani

Satish C Singh

Adrian Douglas

Manuel Queiser

Junlun Li

Paul D Gerardi

Luis Ayestaran

Alexander Nikolov

A method can include receiving pressure data with respect to time acquired via a pressure sensor disposed in an uphole region of a bore of a well, where a plug is disposed in the bore to define the uphole region to one side of the plug and a corresponding downhole region to the other side of the plug; using at least physical properties of liquid in the uphole region and thermal information, computing a temperature and gravitational head induced density variation of the liquid in the uphole region; and, based at least in part on at least a portion of the pressure data and the temperature and gravitational head induced density variation of the liquid, determining a state of the plug and the bore from a plurality of states.

Bore plug analysis system

Systems and methods presented herein generally relate to a tool for determining a refractive index of a formation fluid using attenuated total reflection. The tool includes a body having a fluid admitting assembly and a flow line that receives the formation fluid. The tool also includes two different crystals having faces in contact with fluid in the flow line. The tool further includes at least one light source coupled to the crystals and configured to direct light into the crystals. In addition, the wavelength, the refractive indices, and the angles of incidence are configured such that the light undergoes total internal reflection at interfaces between the crystals and the formation fluid. The tool also includes at least one light detector coupled to the crystals and configured to measure reflected light exiting the crystals. The tool further includes at least one processor coupled to the at least one light detector.

Attenuated total reflection based measurement of refractive index and carbon dioxide concentration

Embodiments presented provide for a method to negate debonding of the casing from a cement in a wellbore. In one embodiment, the cement around the casing is set with a sufficiently large residual compressive stress, preventing the deboning.

Preserving wellbore integrity during carbon dioxide injection

A wellbore is plugged using a bismuth alloy. The wellbore is arranged so that a liquid bismuth alloy sets with an excess pressure of the plug relative to the borehole fluid pressure along a desired seal height distance.

Methods, apparatus and systems for creating wellbore plugs for abandoned wells

A wellbore is plugged using a bismuth alloy. In one embodiment, the bismuth alloy comprises an alloy of bismuth and tin. In another embodiment, the bismuth alloy comprises an alloy of bismuth and silver. The wellbore can be arranged so that a liquid bismuth alloy sets with an excess pressure of the plug relative to the borehole fluid pressure along a desired seal height distance. Other aspects are described and claimed.

Methods, apparatus and systems for creating bismuth alloy plugs for abandoned wells

Methods for interpreting pressure transient tests and predicting future production for a well are provided. In one embodiment, a method for predicting future production includes beginning a pressure transient test within a well at a wellsite and obtaining pressure measurements of well fluid during the pressure transient test. The method can also include using the obtained pressure measurements to determine probabilistic estimates of input parameters of a pressure transient reservoir model while continuing the pressure transient test. Future production from the well can then be estimated based on the probabilistic estimates of the input parameters. Other methods and systems are also disclosed.

Method for real-time interpretation of pressure transient test

Methods and systems are provided for controlling gas lift in at least one production well, which determine a quadratic function that relates flow rate or value of oil produced from a production well to gas flow rate for gas injected into the production well based on flow rate measurements for gas injected into the production well and corresponding flow rate measurements of oil produced from the production well. The quadratic function is used to determine an optimal flow rate for gas injected into the production well. The optimal flow rate for gas injected into the production well is used to control the flow rate of gas injected into the production well, and an oil flow rate produced from the production well is measured at the optimal gas flow rate for iterative processing to refine the quadratic function and determination of optimal gas flow rate if need be.

Autonomous optimization of single-well and multi-well gas lift

Methods are provided for adaptive optimization of enhanced oil recovery project performance under uncertainty. Predictive physics-based reservoir simulation is used to estimate performance of the project. Input parameters of the model are divided into control variables and uncertain variables. The reservoir model is optimized to obtain values of control variables maximizing mean value of a chosen performance metric under initial uncertainty of formation and fluid properties. An efficient frontier can characterize dependence between the optimized mean value of the performance metric and its uncertainty expressed by the standard deviation. Global sensitivity analysis (GSA) is then applied to quantify and rank contributions from uncertain input parameters to the standard deviation of the optimized values of the performance metric. Additional measurements can be performed to reduce uncertainty in the high-ranking parameters. Constrained optimization of the model with reduced ranges of uncertain parameters is performed and a new efficient frontier is obtained.

Methods for adaptive optimization of enhanced oil recovery performance under uncertainty

A method includes operating a downhole acquisition tool in a wellbore in a geological formation and performing formation testing using the downhole acquisition tool in the wellbore to determine at least one measurement associated within the geological formation, the wellbore, or both. The downhole acquisition tool includes one or more sensors that may detect the at least one measurement and the at least one measurement includes formation pressure, wellbore pressure, or both. The method also includes using a processor of the downhole acquisition tool to obtain a response characteristic associated with the formation, the wellbore, or both based on oscillations in the at least one measurement and determining at least one petrophysical property of the geological formation, the wellbore, or both, based on the response characteristic. The petrophysical property includes permeability, mud filter cake permeability, or both.

Downhole characterization of formation pressure

A method includes operating a downhole acquisition tool in a wellbore in a geological formation and performing formation testing to determine at least one measurement associated within the formation, the wellbore, or both. The tool may include sensors to detect measurements including, for example, formation pressure and/or wellbore pressure. The tool may also include a processor to obtain at least one spectral characteristic associated with the measurement, which may include frequencies of oscillation. The processor may also determine one or more parameters, associated with an oscillation suppression process, based on the spectral characteristic and remove oscillations, including noise associated with fluctuations of a fluid level in the wellbore, in the measurement based on the parameters. Petrophysical parameters may be estimated based on the modified measurement.

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Boxborough, MA, United States of America

Terizhandur S Ramakrishnan