Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Fikri John Kuchuk

Terizhandur S Ramakrishnan

Cosan Ayan

Andrew John Carnegie

Raghu Ramamoorthy

Thomas J Neville

Tarek M Habashy

Anthony J Fitzpatrick

Bernard Montaron

Valery Vasilievich Shako

James G Filas

Vyacheslav Pimenov

Lang Zhan

Mustafa Onur

Kirsty Morton

Richard Booth

Edward Harrigan

Peter S Hegeman

Lawrence James Leising

Nikita Chugunov

Anthony Goodwin

Stephane Hiron

Yusuf Bilgin Altundas

Dhandayuthapani Kannan

Sukru Sarac

Ashok Belani

Alexander Starostin

Bertrand Theuveny

Pavel Evgenievich Spesivtsev

Denis Biryukov

Fernando Mattos

Alpaslan Z Tengirsek

Ashok K Belani

Adrian Douglas

Luis Ayestaran

Kristy Morton

Ihsan Murat Gok

Ian Falconer

Saygi Gokhan

An apparatus for performing a well test operation includes a tubular member having a surge chamber and a valve that can control fluid flow from a well into the surge chamber during the well test operation. The apparatus can also include a flow control device, in addition to the valve, for further controlling fluid flow into the surge chamber from the well. Flow rate and pressure data can be measured during the well test operation and used to estimate reservoir properties. Various other systems, devices, and methods are also disclosed.

Closed chamber impulse test with downhole flow rate measurement

Techniques for modelling a production forecast for a well are described. In one embodiment, a method includes calibrating a geological reservoir model by analyzing pressure transient well tests, fitting the geological reservoir model to pressure data to estimate model parameters, and building a simulated history of bottom hole pressure based on the model and measured transient flow data. The calibrating may further include fitting the model to flow rate data, using measured and simulated pressure data as input, to estimate model parameters, and then building a simulated history of downhole flow rate based on the model and change in measured pressure data. The calibrated model can be used to forecast future well production. Additional methods, systems, and devices are also disclosed.

Integrated interpretation of pressure and rate transients for production forecasting

Method for using sensitivity analysis to inform the design and performance of a well test are provided. In one embodiment, a method includes providing a reservoir model of pressure transient behavior and performing a sensitivity analysis to identify an input parameter of the reservoir model that can be estimated from pressure transient test data collected from a well location. This method also includes using the results of the sensitivity analysis to design a pressure transient well test for measuring the identified input parameter. Other methods and systems are also disclosed.

Pressure transient test with sensitivity analysis

Measuring a parameter characteristic of a formation in an oil well with a device configured to generate a sensing field within a volume of the formation and cause a flow through the volume in the presence of the sensing field. The device also comprises sensors responsive to changes in the volume, which indicate existent amounts of fluid, such as hydrocarbon and water saturations and irreducible hydrocarbon and water saturations. Measurements may be made before the flow affects the measuring volume and after onset of the flow through the measuring volume.

Formation treatment evaluation

An apparatus and method of measuring a parameter characteristic of a rock formation in an oil well is provided with a device for generating a sensing field within a volume of the rock formation and a device for causing a flow through the volume in the presence of the sensing field, further including sensors responsive to changes in the volume, wherein a sensor response is indicative of the amounts of fluid, particularly hydrocarbon and water saturations and irreducible hydrocarbon and water saturations. Measurements can be made before the flow affects the measuring volume and after onset of the flow through the measuring volume.

Tool and method for determining formation parameter

Method is directed to determining a fluid influx profile and near-wellbore area parameters in multi-layered reservoirs. A bottomhole pressure in a wellbore is measured. After operation of the wellbore at a constant production rate, the production rate is changed. A bottomhole pressure is measured together with a fluid influx temperature for each productive layer. Graphs of the fluid influx temperature measured as a function of time and of a derivative of this temperature with respect to a logarithm of a time passed after the production rate is changed as a function of time are plotted. Relative production rates and skin factors of the productive layers are calculated based on these graphs.

Method of determination of fluid influx profile and near-wellbore space parameters

Method for determination of a fluid influx profile and near-wellbore area parameters comprises measuring a first bottomhole pressure and after operating a well at a constant production rate changing the production rate and measuring a second bottomhole pressure. A wellbore fluid temperature over an upper boundary of a lowest productive layer and wellbore fluid temperatures above and below other productive layers are measured and relative production rates and skin factors of the productive layers are calculated from measured wellbore fluid temperatures and measured first and second bottomhole pressures.

Method for determination of fluid influx profile and near-wellbore area parameters

Based on measurements that are obtained from a well test, a pressure in the well is modeled as a function of at least a skin effect factor that varies with time. The results of the modeling may be used to estimate at least one well parameter, such as a formation parameter and/or a well pressure, as examples.

Interpreting well test measurements

A method for determining rock and fluid properties of a fluid-containing subsurface geological formation is provided. First, a low resolution model of the geological formation is initially created from a lumped average parameter estimation derived from at least fluid pressure transient data obtained along a linear wellbore that traverses the formation. Next, the model parameters are updated using grid-based parameter estimation in which the low resolution pressure transient data are combined with data from at least one of seismic data, formation logs, and basic geological structural information surrounding the linear wellbore. Depending on the data available, this process may be carried out in a sequential manner by obtaining and combining additional dynamic data at selected areas. Through this process, multiple realizations of the properties of the geological formation (within the geological structural model) may be created based from the pressure-data conditioned geostatistics i.e. geostatistics that have been informed by data from both static and dynamic sources. Finally, the dynamic simulation of models should be compared to the results of the lumped average parameter estimation to provide a final calibration of the created models.

Method for integrated inversion determination of rock and fluid properties of earth formations

A method for determining permeability of a reservoir using a packer-probe formation testing tool. The elements of the method include generating, using a dual packer tool module, fluid flows from the reservoir into a wellbore, obtaining pressure data associated with the fluid flows using an observation probe tool module, wherein the packer-probe formation testing tool comprises the dual packer module and the observation probe tool module, identifying a portion of the pressure data corresponding to a spherical flow regime, determining horizontal permeability based on the portion of the pressure data, and displaying an output generated using the horizontal permeability.

Thickness-independent computation of horizontal and vertical permeability

A method of installing a sensor system for making pressure measurements in downhole formations surrounding a wellbore includes placing a sensor in direct pressure communication with the formations from a predetermined position in the wellbore; and isolating the sensor with an elastomeric sealing means placed against the formation wall in order to prevent hydraulic pressure communication between the sensor and the inside of the wellbore.

Downhole 4D pressure measurement apparatus and method for permeability characterization

An example instrumented formation tester for injecting fluids and monitoring of fluids described herein includes a downhole tool which can be deployed in a wellbore via a wireline or a drill string. The downhole tool may facilitate the injection of fluids into an underground formation, and the monitoring of the directions in which the injected fluids flow in the formation in an open hole environment. In particular, the downhole tool may be configured for removing the mud cake from a portion of the wellbore wall for facilitating a fluid communication with the formation to be tested.

Instrumented formation tester for injecting and monitoring of fluids

A system for making pressure measurements in a formation surrounding a wellbore includes a sensor which, in use, is positioned into direct pressure communication with the formation from a predetermined location in the wellbore, and a means for isolating the sensor, when in use, from pressure effects arising from the wellbore.

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Meudon, France

Fikri John Kuchuk