Saudi Arabian Oil Company

Vladimir Kazei

Younane N Abousleiman

Chao Liu

Konstantin Osypov

Dung T Phan

Ezzedeen Alfataierge

Harold Merry

A method of determining rock matrix and fracture permeability to perform a reservoir fluid flow simulation. The method includes: obtaining a petrophysical characterization of a formation sample, measuring a first and second elastic wave velocity of the formation sample at a first and second frequency, calculating an average rock matrix density and an average porosity of the formation sample, determining a set of calculated elastic wave velocities for the first and second frequencies over a range of candidate permeabilities, and determining a rock matrix permeability and a fracture permeability based on the set of calculated elastic wave velocities at the first and second frequency respectively. The method further including performing a reservoir fluid flow simulation based, at least in part, on at least one of the rock matrix permeability and the fracture permeability.

Method for determining rock matrix and fracture permeability by using poroelastodynamics and density averaging schemes

A system may include a wellbore extending a first depth into a formation. Additionally, a cured-in-place pipe liner may be coupled to walls of the wellbore. One or more fiber optic cables are embedded in the cured-in-place pipe liner to monitor a curing of the cured-in-place pipe liner and record well data. The one or more fiber optic cables may be used to continuously monitor the wellbore during a method for lining the wellbore is performed. The method for lining the wellbore may include inserting the cured-in-place pipe liner into the wellbore; forcing the cured-in-place pipe liner against walls of the wellbore; curing the cured-in-place pipe liner; monitoring the curing of the cured-in-place pipe liner with the one or more fiber optic cables embedded in the cured-in-place pipe liner; and coupling the cured-in-place pipe liner to the walls of the wellbore.

System and method for deploying fiber optic cables with a cured-in-place pipe liner

A method and system for measuring strain rate at a scale shorter than gauge length are disclosed. The method includes deploying a plurality of discrete seismic receivers and a distributed acoustic system (DAS) in a borehole extending into a formation. The method further includes obtaining a first DAS measurement (DAS1) between a first position and a second position, obtaining a second DAS measurement (DAS2) between a third position and a fourth position, and obtaining a discrete seismic receiver measurement between the second position and the fourth position. The method further includes determining an DAS equivalent discrete measurement (DASeq) from the discrete seismic receiver measurement, determining a sub-gauge DAS measurement (DASsg) based, at least in part, on the first DAS measurement, the second DAS measurement and the DAS equivalent discrete measurement, and determining mechanical characteristics of the formation based, at least in part, on the sub-gauge DAS measurement.

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Houston, TX, United States of America

Vladimir Kazei