Halliburton Energy Services, Inc.

Sami Abbas Eyuboglu

Mark Anton Proett

Li Gao

Tony Herman Van Zuilekom

Abdolhamid Hadibeik

Songhua Chen

Dingding Chen

Anthony Herman Van Zuilekom

Cyrus A Irani

Lilong Li

Ronald Johannes Dirksen

Waqar Ahmad Khan

Daniel Robert Buller

Rohin Naveena Chandran

Michael T Pelletier

Calvin Kessler

A method and system for downhole, real-time determination of relative permeability with nuclear magnetic resonance and formation testing measurements is provided. The method includes introducing a nuclear magnetic (NMR) tool and a formation testing tool into a well bore penetrating a subterranean formation. The method also includes measuring a saturation of a fluid in the subterranean formation from the NMR tool, measuring a mobility of the fluid from the formation testing tool, and measuring a viscosity of the fluid. The method includes calculating a relative permeability of the subterranean formation based on the measured saturation, the measured viscosity and the measured mobility. The method also includes providing a reservoir production prediction metric based on the calculated relative permeability of the subterranean formation for facilitating a well completion operation in the wellbore.

Downhole, real-time determination of relative permeability with nuclear magnetic resonance and formation testing measurements

A method of evaluating fluid sample contamination is disclosed. A formation tester tool is introduced into a wellbore. The formation tester tool comprises a sensor. Sensor data is acquired from the sensor and a contamination estimation is calculated. A remaining pump-out time required to reach a contamination threshold is then determined.

Method and apparatus for evaluating fluid sample contamination by using multi sensors

Methods for determining the quality of data gathered in a wellbore in a subterranean formation including (a) collecting a formation fluid sample in the wellbore in the subterranean formation using a formation tester for receiving the formation fluid, wherein the formation tester is lowered to at least one depth in the wellbore in the subterranean formation by a conveyor; (b) acquiring a wellbore measurement ('WM') from the least one depth with the formation tester; (c) determining from the WM a measured quality value ('MQV'); (d) assigning a threshold value (&#x201c;TV&#x201d;) to the MQV; (e) assigning a range value (&#x201c;RV&#x201d;) to the MQV, based on geometric scaling of the TV, the RV defining the limits of the MQV above and below the TV; and (f) calculating a score value (&#x201c;SV&#x201d;) based on the MQV, the TV, and the RV, wherein the SV is a number between 0 and 2*TV, and wherein the quality of the WM increases as the SV increases.

Determining the quality of data gathered in a wellbore in a subterranean formation

A method of determining a reservoir parameter of a subterranean formation comprising: initiating an initial pressure pulse in the subterranean formation; initiating a series of subsequent pressure pulses in the subterranean formation until the reservoir parameter may be determined, wherein each subsequent pressure pulse is optimized utilizing analytical and/or numerical simulation models; and determining the reservoir parameter.

Automatic optimizing methods for reservoir testing

In situ density and compressibility of a fluid sample are determined for a fluid sample collected downhole. The density and compressibility of the fluid sampled is determined by measuring a distance to a piston contained within the sample chamber using an external magnetic field sensor that senses a magnetic field emanating from a magnet provided on the piston internal to the sample chamber. The testing is performed quickly and at the surface in a noninvasive fashion (e.g., without opening the sample chamber).

Non-invasive compressibility and in situ density testing of a fluid sample in a sealed chamber

A method of measuring parameters of a formation along multiple axes is disclosed. A formation tester tool is introduced into a wellbore. The formation tester tool includes a first probe oriented at an angle from a second probe about an axis of the formation tester tool. The first and second probes are positioned against a surface of the wellbore. Fluid is injected via at least one of the first and second probes. Pressure parameters corresponding to the fluid injected into the formation are monitored. Formation stresses about the formation fractures along multiple axes are determined based, at least in part, on the pressure parameters.

Systems and methods for measuring parameters of a formation

In situ density and compressibility of a fluid sample are determined for a fluid sample collected downhole. The density and compressibility of the fluid sample is determined by measuring a distance to a piston contained within the sample chamber using an external magnetic field sensor that senses a magnetic field emanating from a magnetic provided on the piston internal to the sample chamber. The testing is performed quickly and at the surface in a noninvasive fashion (i.e., without opening the sample chamber).

Growing community of inventors

Conroe, TX, United States of America

Sami Abbas Eyuboglu