Schlumberger Technology Corporation

Cameron International Corporation

Geoservices Equipements

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Logined B.v.

Andrew Emil Pomerantz

Oliver Clinton Mullins

Youxiang Zuo

Paul Ryan Craddock

Andrew Speck

Denise E Freed

Ridvan Akkurt

Vinay K Mishra

Hadrien Dumont

Thomas Pfeiffer

Dean Michael Willberg

Christopher Harrison

Robert L Kleinberg

Cosan Ayan

Ravinath Kausik Kadayam Viswanathan

Albert Ballard Andrews

Richard E Lewis

Romain Charles Andre Prioul

Frank Shray

Dingan Zhang

Eric Lehne

Julian Youxiang Zuo

Soraya S Betancourt Pocaterra

Jerimiah Forsythe

Thorarinn Kristjansson

Yi-Qiao Song

Syed Afaq Ali

Kang Wang

Wael Abdallah

Iain Michael Cooper

Gocha T Chochua

Chengli Dong

Soumyajit Mandal

Michael M Herron

Kashif Rashid

Michael David Prange

John E Edwards

Jeffrey Miles

Soraya Sofia Betancourt

Raphael Gadot

George Alan Waters

Erik Rylander

Li Chen

Francois Xavier Dubost

Shu Pan

Jerome Breviere

Mikhail Stukan

Sophie Nazik Godefroy

German Garcia

A Ballard Andrews

Yi Chen

Albina Mutina

Morten Kristensen

Anish Kumar

Vladislav Achourov

Robert Allen Badry

Adrian Rodriguez Herrera

Armin Kauerauf

Daniel M Tetzlaff

Glen Andrew Hay

Raphael Altman

John J Valenza, Ii

Jesus Alberto Canas

Athithan Dharmaratnam

John Waggoner

Stacy Lynn Reeder Blanco

Mary Ellen Loan

Karl Staffan Tekin Eriksson

Adam Huynh

Laurent Mosse

Zulfiquar Ail Reza

Roderick Bovee

Salman Khalid

Kenneth Faurschou

Manuel Aboud

Joseph Carl Fiduk

Zied Ben Hamad

Tobias Judd

Chengil Dong

Methods and apparatus for fugitive emission detection. In some embodiments, the method can include planning and performing aerial inspections of a plurality of structures within one or more facilities by determining a flight path for a scanning of fugitive emissions from a plurality of structures within one or more facilities. The flight path can cover a set of structure clusters that can be serviced by a base. The method can also include using a computer-implemented clustering method to identify the set of structure clusters that can be serviced by the respective base. The clustering method can be a hierarchical multilevel clustering method. The method can also include scanning the plurality of structures for fugitive emissions using an airborne sensor. The airborne sensor can be mounted to a flight vehicle launched from the base. The method can also include classifying the plurality of structures based on results of the scanning.

Optimized multi-stage intermittent fugitive emission detection

Systems and methods presented herein generally relate to determining flaring efficiency of a flare based at least in part on radiant or thermal heat generated by the flare that is detected by one or more flare monitors. In particular, in certain embodiments, a control system may be used to determine a flaring efficiency of the combustion of the flare gas at the tip of the flare based at least in part on the radiant or thermal heat detected by the one or more flare monitors.

Radiant heat or thermal based flare efficiency monitoring

A system and method using a subterranean biological reactor can include a pre-reactor storage unit configured to receive a feedstock including a slurry of biologically derived material and at least one pump configured to pump the effluent from the pre-reactor storage unit. The system may include at least one wellbore containing a subterranean biological reactor configured to receive the effluent from the pre-reactor storage unit. At least a portion of the subterranean biological reactor may be configured to perform anaerobic digestion upon the effluent to generate a biogas.

System and method for using subterranean biological reactors

Systems and methods presented herein generally relate to greenhouse gas emission monitoring and, more particularly, to a greenhouse gas emission monitoring workflow using various different types of sensors. For example, a system includes a plurality of sensors located within an oil and gas worksite. At least one sensor of the plurality of sensors is configured to detect a status of equipment at the oil and gas worksite. The system also includes a greenhouse gas emission analysis system configured to receive sensor data from the plurality of sensors. The greenhouse gas emission analysis system is also configured to correlate the sensor data from the plurality of sensors (e.g., using one or more reduced order models (ROMs) that reduce the computational complexity of computational fluid dynamics model simulations of previously collected data relating to operation of the oil and gas worksite). The greenhouse gas emission analysis system is further configured to determine an existence of a greenhouse gas emission within the oil and gas worksite, a location of the greenhouse gas emission within the oil and gas worksite, and a quantity of the greenhouse gas emission within the oil and gas worksite based at least in part on the correlation.

Greenhouse gas emission monitoring systems and methods

Embodiments of the present disclosure are directed towards a method for improving neutron interpretations in a subsurface formation. Embodiments may include estimating mineral concentrations and kerogen concentrations at one or more depths in the subsurface formation and determining kerogen properties at one or more depths in the subsurface formation. Embodiments may further include calculating mineral properties at one or more depths in the subsurface formation and calculating a neutron-based log response to a rock matrix based upon, at least in part, the kerogen properties and the mineral properties at one or more depths in the subsurface formation by subtracting.

Method for improving neutron interpretations in subsurface formations

A technique facilitates detection of gaseous emissions in a marine environment via a vessel or vessels traversing a region of the marine environment. Environmental data is collected via a detection system on each vessel and communicated to a processing system. The processing system processes various environmental data such as location data, emission detection data, wind data, and/or other data to determine an emissions result. This emissions result is output in a form to facilitate decision-making with respect to potential corrective actions to reduce the gaseous emissions.

Marine emissions detection

A methodology that performs fluid sampling within a wellbore traversing a reservoir and fluid analysis on the fluid sample(s) to determine properties (including asphaltene concentration) of the fluid sample(s). At least one model is used to predict asphaltene concentration as a function of location in the reservoir. The predicted asphaltene concentrations are compared with corresponding concentrations measured by the fluid analysis to identify if the asphaltene of the fluid sample(s) corresponds to a particular asphaltene type (e.g., asphaltene clusters common in heavy oil). If so, a viscosity model is used to derive viscosity of the reservoir fluids as a function of location in the reservoir. The viscosity model allows for gradients in the viscosity of the reservoir fluids as a function of depth. The results of the viscosity model (and/or parts thereof) can be used in reservoir understanding workflows and in reservoir simulation.

Method for characterization of hydrocarbon reservoirs

A method includes receiving first fluid property data from a first location in a hydrocarbon reservoir and receiving second fluid property data from a second location in the hydrocarbon reservoir. The method includes performing a plurality of realizations of models of the hydrocarbon reservoir according to a respective plurality of one or more plausible dynamic processes to generate one or more respective modeled fluid properties. The method includes selecting the one or more plausible dynamic processes based at least in part on a relationship between the first fluid property data, the second fluid property data, and the modeled fluid properties obtained from the realizations to identify potential disequilibrium in the hydrocarbon reservoir.

Reservoir fluid geodynamic system and method for reservoir characterization and modeling

Systems and methods for identifying a likelihood that a reservoir of a geological formation received a secondary charge of hydrocarbons of relatively very different thermal maturity of composition are provided. One method includes positioning a downhole acquisition tool in a wellbore in a geological formation and testing one or more fluid properties of the formation fluid. Data processing circuitry may identify whether a relationship of the one or more fluid properties exceeds a first threshold that indicates likely asphaltene instability. When this is the case, data processing circuitry may be used to model the geological formation using a realization scenario in which multiple charges of hydrocarbons of substantially different thermal maturity or substantially different composition, or both, filled a reservoir of the geological formation over geologic time.

Systems and methods for identifying two or more charges into reservoir using downhole fluid analysis

Methods may include estimating the weight fractions of kerogen and inorganic mineral components of at least an interval of a subsurface formation; determining the grain density of kerogen and inorganic mineral components, wherein at least the grain density of kerogen is determined by one or more infrared measurements; and calculating the formation matrix density of at least an interval of the subsurface formation from the estimated weight fractions and the determined grain density. In another aspect, methods may include estimating the weight fractions of kerogen and inorganic mineral components of at least an interval of a subsurface formation; determining the grain density of kerogen and inorganic mineral components, wherein at least the grain density of kerogen is determined by one or more infrared measurements; and calculating the formation matrix density of at least an interval of the subsurface formation from the estimated weight fractions and the determined grain density; calculating the bulk density for at least an interval of the subsurface formation; and determining the total porosity of at least an interval of the subsurface formation as a function of depth by combining the calculated formation matrix density and the calculated bulk density.

Methods for improving matrix density and porosity estimates in subsurface formations

Fluid property modeling that employs a model that characterizes asphaltene concentration gradients is integrated into a reservoir modeling and simulation framework to allow for reservoir compartmentalization (the presence or absence of flow barrier in the reservoir) to be assessed more quickly and easily. Additionally, automated integration of the fluid property modeling into the reservoir modeling and simulation framework allows the compositional gradients produced by the fluid property modeler (particularly asphaltene concentration gradients) to be combined with other data, such as geologic data and other petrophysical data, which allows for more accurate assessment of reservoir compartmentalization.

Method and systems for reservoir modeling, evaluation and simulation

Treatment methods and treatment fluids for increasing permeability of organic shale formations are described herein. The treatment method includes treating an organic shale formation with a treatment fluid. The treatment fluid includes a solvent that dissolves bitumen in the shale formation. After treating the shale formation with the treatment fluid, oil is recovered from the shale formation. By removing bitumen from pores and pore throats within the formation, the solvent increases permeability of the formation and allows mobile oil to flow more easily through the formation.

Method for removing bitumen to enhance formation permeability

A method for estimating a value of a kerogen property in a subsurface formation where the value of the kerogen property is unknown. The method includes: measuring spectral intensity values over an infrared (IR) spectral range for a selected sample from the subsurface formation; determining a range of values representing the measured spectral intensity values corresponding to a vibrational mode attributable to kerogen in the selected sample, the range of values including values representing uncertainty in the measured spectral intensity over the portion of the spectral range; and inputting values from the range of values into a stochastic or simple regression model to determine an estimated value of the kerogen property in the selected sample.

Method for estimating a value of a kerogen property in subsurface formations

A method for analyzing a geological formation having at least one hydrocarbon therein may include determining a total organic carbon mass over a depth range of the geological formation, and determining a mass fraction of the at least one hydrocarbon over the depth range of the geological formation based upon the total organic carbon mass. The method may further include determining a volume of the at least one hydrocarbon over the depth range of the geological formation, and determining a density of the at least one hydrocarbon over the depth range of the geological formation based upon the mass fraction and the volume of the at least one hydrocarbon.

Hydrocarbon density determination method

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Lexington, MA, United States of America

Andrew Emil Pomerantz