Schlumberger Technology Corporation

Saudi Arabian Oil Company

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Martin E Poitzsch

Peter Speier

Hooisweng Ow

Julian J Pop

Jason R Cox

Krishnamurthy Ganesan

Hsieh Chen

Feng Liang

Ghaithan Al-Muntasheri

Bruno Luong

Wei Wang

Pabitra N Sen

Muthusamy Vembusubramanian

Guillemette Picard

Karen Wiemer

Reza Taherian

Jacques R Tabanou

Sehoon Chang

Shu-Kong Chang

Jaideva C Goswami

Ralf Heidler

Steven F Crary

Gawain Thomas

Daniel T Georgi

Yi-Qiao Song

Martin D Hurlimann

Julius Kusuma

Alberto F Marsala

David G Cory

Klemens Katterbauer

Tancredi Botto

Nouf Jabri

Benjamin Levitt

Karim Ismail

Benjamin Peter Jeffryes

Arthur H Hartog

Shouxiang Mark Ma

Bradley Albert Roscoe

Hubertus V Thomeer

Amr Ismail Abdel-Fattah

Martin G Luling

Ayrat Gizzatov

Shitong Sherry Zhu

Cengiz Esmersoy

Mark A Fredette

S Sherry Zhu

Marta Antoniv

Chicheng Xu

Tim Hopper

Timothy Andrew John Hopper

Roger A Dworak

Ivan Cetkovic

Mohammed R Kawelah

Ben Levitt

A method for constructing a high fidelity logging while drilling (LWD) log that includes obtaining a temporal well depth log and a plurality of temporal LWD logs from a drilling operation. The method further includes obtaining a temporal record of operational drilling parameters from the drilling operation. The method further includes determining, using a first machine-learning model, a temporal history of the drilling operation and constructing, using the temporal well depth log and the plurality of temporal LWD logs, a plurality of temporal property logs at each depth in the plurality of depths. The method further includes processing the plurality of temporal property logs with, at least, a second machine-learning model to form a plurality of corrected temporal property logs and aggregating the plurality of corrected temporal property logs to form a plurality of high fidelity LWD logs.

Using artificial intelligence methods to exploit well logging data

A method for monitoring waterfront movement in a subsurface formation involves performing forward modeling of at least one deep electromagnetic survey of the waterfront movement, and determining locations for installing an electrically insulating spacer between well liners to form an on-demand electromagnetic source electrode. Based on the forward modeling, repeat survey time intervals are predicted. The method involves, during well completion, installing the electrically insulating spacer between the well liners in a reservoir to form at least one on-demand electromagnetic source electrode, and installing the electrically insulating spacer between the plurality of well liners in a reservoir to form an on-demand electromagnetic receiver electrode. A waterfront survey is performed by conveying a production logging tool into a well that temporarily converts the well liners into an on-demand electromagnetic source electrode and an on-demand receiver electrode, and inverse modeling of the waterfront survey is performed to produce a water saturation image.

Waterflood front imaging using segmentally insulated well liners as on-demand electrodes

Hydrocarbon flow into multi-lateral wells is analyzed by controlled release of tracers from the surface. Hydrocarbons flow into a lateral formed from a wellbore into a subterranean zone. A wellbore production tubing is installed within the wellbore and extends toward the lateral. The wellbore production tubing defines an annulus between an outer surface of the tubing and an inner wall of the wellbore. Hydrocarbons flowing from the lateral into the annulus flow within an internal volume defined by a body attached to the outer surface of the tubing. The hydrocarbons mix with tracers residing within the internal volume. A mixture of the hydrocarbons with the tracers flow out of the internal volume and towards the surface. At the surface, a concentration of the tracers in the mixture flowed to the surface is analyzed. Based on a result of the analyzing, properties of hydrocarbon flow into the lateral are determined.

Analyzing hydrocarbon flow into multi-lateral wells by releasing tracers from the surface

Methods and systems for determining electrical characteristics of a subsurface formation are disclosed. The method may include installing a first electrically insulating spacer between well liners in the well to form an on-demand electromagnetic source electrode and installing a second electrically insulating spacer between well liners in the well to form an on-demand electromagnetic receiver electrode. The method may further include performing an electrical survey using the on-demand electromagnetic source and receiver electrodes, determining a map of the at least one electrical characteristic in a subsurface region surrounding on-demand electromagnetic source and receiver electrodes based on the electrical survey, determining a map of at least one formation property based on the map of the electrical characteristic, and updating a hydrocarbon reservoir production plan based on the map of at least one formation property.

Concurrent oil saturation and porosity imaging using completion-based on-demand electrodes

A method and a system for injecting multiple tracer tag fluids into the wellbore are described. The method includes determining multiple injection concentrations of multiple respective tracer tag fluids, determining an injection sequence of the tracer tag fluids into a wellbore, and injecting the tracer tag fluids into the wellbore according to the injection concentrations and the injection sequence. The tracer tag fluids include synthesized polymeric nanoparticles suspended in a solution. The synthesized polymeric nanoparticles are configured bind to a wellbore cutting. The synthesized polymeric nanoparticles are configured to undergo a thermal de-polymerization at a respective temperature and generate a unique mass spectra. The injection sequence includes an injection duration determined by a depth interval of the wellbore to be tagged by the synthesized polymeric nanoparticles and an injection pause to prevent mixing the multiple tracer tag fluids in the wellbore.

Injecting multiple tracer tag fluids into a wellbore

According to one or more embodiments, a method of growing crystals on a QCM sensor may include treating a crystal growth surface of the QCM sensor with a coupling agent, applying a cation stream to the crystal growth surface of the QCM sensor, and applying an anion stream to the crystal growth surface of the QCM sensor. The crystals forming a crystal layer may have an average thickness greater than 5 nanometers. According to one or more embodiments, a QCM sensor may include a crystal layer on a crystal growth surface of the QCM sensor, where the crystal layer is formed by a process including treating the crystal growth surface of the QCM sensor with a coupling agent, applying a cation stream to the crystal growth surface of the QCM sensor, and applying an anion stream to the crystal growth surface of the QCM sensor.

Methods for growing crystals on QCM sensors

A wellbore that supplies production fluid from a first production zone and a second production zone is produced. Production fluids from the first and second production zone are comingled within a same production tubular. A first tracer is pulsed into the first production zone. A second tracer is pulsed into the second production zone. The first tracer and the second tracer are barcoded such that the first tracer and the second tracer can be differentiated from one another. A first tracer decay is measured at a topside facility. A second tracer decay is measured at the topside facility. A water cut of the first production zone and the second production zone is determined based upon the first tracer decay and the second tracer decay.

Determining oil and water production rates in multiple production zones from a single production well

A method for mapping inter-well porosity includes injecting a Type 1 tracer into a hydrocarbon-bearing reservoir via an injector well, wherein the Type 1 tracer is a passive tracer, injecting a Type 2 tracer into the hydrocarbon-bearing reservoir via the injector well, wherein the Type 2 tracer is a porosity-sensitive tracer, detecting a breakthrough of the Type 1 tracer and a breakthrough of the Type 2 tracer in produced fluid at a producer well, and comparing the breakthrough of the Type 1 tracer with the breakthrough of the Type 2 tracer to provide a map of inter-well porosity.

Mapping inter-well porosity using tracers with different transport properties

Spherical grains and sacrificial particles are mixed in a suspension. The sacrificial particles are larger than the spherical grains. The suspension is injected into a channel in a microfluidic chip, and the spherical grains form microporous structures in the channel. The microporous structures are sintered in the channel. A solvent is injected into the channel, and the solvent dissolves the sacrificial particles and forms macropores between at least some of the microporous structures, thereby forming a mixed-porosity microfluidic chip.

Microfluidic chip with mixed porosities for reservoir modeling

A system and method for flow synthesis of polymer nanoparticles in a continuous flow reactor having a channel. The polymer nanoparticles are synthesized from monomer in the presence of an initiator.

Flow synthesis of polymer nanoparticles

A system for drilling a wellbore is disclosed. The injection pump releases the taggant into the mud stream traveling downhole. The taggant attaches to the rock cuttings and it is detected on the surface by the taggant detector. The taggant detector provides the data relating to the taggants detected in the drilling fluid. The data is analyzed by taggant analysis and control engine, which produces an injection profile. Based on the injection profile, the IoT Controller adapts the parameters of the taggant injection pump to achieve a real-time optimization of the taggant injection.

Systems and methods for drilling a wellbore using taggant analysis

A blocking material is injected into a microfluidic chip that includes microscale-porosity microchannels etched in a substrate, filling at least a portion of the microchannels. Silicon dioxide spheres are injected into the microfluidic chip. The blocking material prevents the silicon dioxide spheres from entering the portion of the microchannels filled with the blocking material. The silicon dioxide spheres form a region of nanoscale porosity in a portion of the microchannels not filled with the blocking material. A solvent is injected into the microfluidic chip, the solvent operable to dissolve the blocking material and thereby providing a region of microscale porosity adjacent to the region of nanoscale porosity.

Microfluidic chip with multiple porosity regions for reservoir modeling

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Derry, NH, United States of America

Martin E Poitzsch