Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Dariusz Strapoc

Oliver Clinton Mullins

Jonathan Robert Hird

Vinay K Mishra

Jerome Breviere

Andrew David Robinson

Mahdi Ammar

Timothy McAlinden

Soraya S Betancourt Pocaterra

Jesus Alberto Canas

Ivan Fornasier

David Scott

Can Evren Yarman

Soraya S Betancourt-Pocaterra

Nicholas Ivars Abolins

A bit to detect drill bit metamorphism (DBM) may include a bit head. A bit to detect DBM may include at least one cutting element connected to the bit head. A bit to detect DBM may include a temperature sensor on or in the at least one cutting element. A bit to detect DBM may include an electronics module in communication with the temperature sensor. A bit to detect DBM may include a wiring conduit from the at least one cutting element and through at least a portion of the bit head to the electronics module.

Drill bit metamorphism detection

An apparatus for making isotopic ethane measurements of a gas sample includes a tunable infrared laser configured to emit an infrared laser beam; an infrared sensor configured to receive the infrared laser beam; a gas cell deployed in a path between the tunable infrared laser and the infrared sensor such that the infrared laser beam passes through the gas cell, the gas cell configured to receive the gas sample; and a controller configured to evaluate the received infrared laser beam to estimate a ratio of C13 ethane to C12 ethane in the gas sample.

Tunable laser spectroscopy measurement of C13 ethane

Various implementations directed to analyzing a reservoir using fluid analysis are provided. In one implementation, a method may include determining mud gas logging (MGL) data based on drilling mud associated with a wellbore traversing a reservoir of interest. The method may also include determining first downhole fluid analysis (DFA) data based on a first reservoir fluid sample obtained at a first measurement station in the wellbore. The method may further include determining predicted DFA data for the wellbore based on the first DFA data. The method may additionally include determining second DFA data based on a second reservoir fluid sample obtained at a second measurement station in the wellbore. The method may further include analyzing the reservoir based on a comparison of the MGL data and a comparison of the second DFA data to the predicted DFA data.

Analyzing reservoir using fluid analysis

Growing community of inventors

Roissy-en-France, France

Dariusz Strapoc