Schlumberger Technology Corporation

Erik Rylander

Richard E Lewis

Ravinath Kausik Kadayam Viswanathan

Ridvan Akkurt

Tarek M Habashy

Lalitha Venkataramanan

Vivek Anand

Laurent Mosse

Badarinadh Vissapragada

Fred K Gruber

Sammy S Haddad

Mansoor Ali

Tianmin Jiang

Syed Afaq Ali

Andrew Emil Pomerantz

Josselin Kherroubi

George Alan Waters

Paul Ryan Craddock

Philip M Singer

Kamilla Fellah

Helena Gamero Diaz

Robert L Jeffries

Roderick Bovee

Glenn Houston

Rahul Joshi

Christina Calvin

Downhole fluid volumes of a geological formation may be estimated using nuclear magnetic resonance (NMR) measurements, even in organic shale reservoirs. Multi-dimensional NMR measurements, such as two-dimensional NMR measurements and/or, in some cases, one or more well-logging measurements relating to total organic carbon may be used to estimate downhole fluid volumes of hydrocarbons such as bitumen, light hydrocarbon, kerogen, and/or water. Having identified the fluid volumes in this manner or any other suitable manner from the NMR measurements, a reservoir producibility index (RPI) may be generated. The downhole fluid volumes and/or the RPI may be output on a well log to enable an operator to make operational and strategic decisions for well production.

Estimating downhole fluid volumes using multi-dimensional nuclear magnetic resonance measurements

The systems and methods provided herein relate to extracting maturity-based properties from input log data obtained by a downhole well logging tool. A maturity inversion is performed using the input log data, a log response model, and at least one maturity model to extract maturity-based properties from the input log data. The maturity-based properties are provided in an output log, such that subsequent down hole operation of the formation may account for the maturity-based properties.

Thermal maturity estimation via logs

A methods are provided for investigating a sample containing hydrocarbons by subjecting the sample to a nuclear magnetic resonance (NMR) sequence using NMR equipment, using the NMR equipment to detect signals from the sample in response to the NMR sequence, analyzing the signals to extract a distribution of relaxation times (or diffusions), and computing a value for a parameter of the sample as a function of at least one of the relaxation times (or diffusions), wherein the computing utilizes a correction factor that modifies the value for the parameter as a function of relaxation time for at least short relaxation times (or as a function of diffusion for at least large diffusion coefficients).

Methods of investigating formation samples using NMR data

A method can include receiving data for a geologic environment where the data include data acquired via different types of borehole tool sensors; based at least in part on the data, determining rock composition of the geologic environment where the rock composition includes depositional components and diagenetic components; and, based at least in part on the rock composition, outputting a stratigraphic model of at least a portion of the geologic environment.

Diagenetic and depositional rock analysis

A method for testing an unconventional core sample is provided. The method involves loading the unconventional core sample into a sample holder and introducing fluid into the sample holder at an elevated pressure such that fluid is injected into the internal pore space of the unconventional core sample in order to resaturate the unconventional core sample with the fluid, wherein the fluid is selected from the group including a hydrocarbon fluid and a water-based formation fluid. An apparatus and a system used in combination with the method are also provided.

Workflow for resaturation and analysis of unconventional core samples

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 and apparatus for testing formations surrounding an earth borehole. The method includes the following steps: providing a tool movable through the borehole; providing a flow line in the tool; establishing fluid communication between the formations and the flow line of the tool; and providing a sand trap in communication with the flow line of the tool for trapping sand flowing with fluid from the formations.

Formation testing apparatus and method

A method is disclosed for determining viscosity and density of fluid from formations surrounding an earth borehole, including the following steps: (a) suspending a formation testing device in the borehole; (b) drawing formation fluid into the device; (c) causing the fluid to flow in a flow line under a first set of conditions; (d) causing the fluid to flow in the flow line under a second set of conditions; (e) measuring a first fluid pressure differential in the flow line during fluid flow under the first set of conditions, and measuring a second pressure differential in the flow line during fluid flow under the second set of conditions; and (f) determining density and viscosity of the fluid as a function of the first and second measured pressure differentials.

Downhole determination of formation fluid properties

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Frisco, TX, United States of America

Erik Rylander