Methods and systems for inspecting the integrity of multiple nested tubulars are provided. A method for inspecting the integrity of multiple nested tubulars can comprise conveying an electromagnetic pipe inspection tool inside the innermost tubular of the multiple nested tubulars; taking measurements of the multiple nested tubulars with the electromagnetic pipe inspection tool; inverting the measurements for a tubular integrity property of each individual tubular of the multiple nested tubulars to provide inverted tubular integrity properties; arranging the inverted integrity properties into an inverted image representative of an estimated tubular integrity property of each individual tubular; and feeding the inverted image to a pre-trained deep neural network (DNN) to produce a corrected image, wherein the DNN comprises at least one convolutional layer, and wherein the corrected image comprises a representation of the tubular integrity property of each individual tubular of the multiple nested tubulars.

Methods and systems for inspecting the integrity of multiple nested tubulars are included herein. A method for inspecting the integrity of multiple nested tubulars can comprise conveying an electromagnetic pipe inspection tool inside the innermost tubular of the multiple nested tubulars; taking measurements of the multiple nested tubulars with the electromagnetic pipe inspection tool; arranging the measurements into a response image representative of the tool response to the tubular integrity properties of the multiple nested tubulars; and feeding the response image to a pre-trained deep neural network (DNN) to produce a processed image, wherein the DNN comprises at least one convolutional layer, and wherein the processed image comprises a representation of the tubular integrity property of each individual tubular of the multiple nested tubulars.

A method for performing a maintenance operation of a well in an oil/gas field. The method includes identifying an extent of corrosion deposit of the well, predicting, using a descaling model of the oil/gas field and based on the extent of corrosion deposit, expected descaling metal loss in a tubular of the well, calculating, based on the expected descaling metal loss, a tubular burst/collapse pressure for a predicted thickness of the tubular, comparing the tubular burst/collapse pressure against a well operating pressure to generate a comparison result, and performing the maintenance operation of the well based on the comparison result.

Compositions and methods for prevention and reduction of iron sulfide scale formation, one method including detecting at least one component indicative of an iron sulfide scale precursor, the at least one component selected from the group consisting of: H.sub.2S; HS.sup.−; S.sup.2−; S.sub.n.sup.2−; FeS.sub.(aq); Fe.sup.2+; Fe.sup.3+, and combinations of the same; preparing a composition to react with the iron sulfide scale precursor, the composition comprising at least one compound selected from the group consisting of: a methylating agent; a metal operable to react with sulfide species; a compound to increase the oxidation state of Fe.sup.2+; and combinations of the same; and applying the composition to the iron sulfide scale precursor to consume the iron sulfide scale precursor.

A tool for monitoring conditions within a subterranean well includes a first body segment, the first body segment being an elongated member with an axial protrusion having a reduced outer diameter. A second body segment is sized for mating with the first body segment. A metal specimen circumscribes the axial protrusion of the first body segment so that an outer diameter surface of the metal specimen defines an outer diameter of the tool. A connection assembly releasably secures the first body segment to the second body segment.

A method for controlling corrosion is described. The method includes determining a concentration of a first gas in a first formation, determining a concentration of a second gas different than the first gas in a second formation, determining a ratio between the first gas and the second gas, comparing the determined ratio to a threshold ratio of the first gas to the second gas for the wellbore which reduces a corrosion rate within the wellbore, and based on a result of comparing the determined ratio to the threshold ratio, modifying a quantity of the first formation fluid or the second formation fluid flowed into the wellbore. The first gas and the second gas mix within the wellbore.

The invention relates to geophysics and can be utilised for monitoring integrity of casings, tubings and other tubular strings in oil and gas wells. The essence of this invention is an apparatus for defectoscopy of downhole casings, which comprises an electromagnetic field generation unit, pick-up sensor unit, and data acquisition and processing unit, with all these units mounted in a housing. The technical result consists in enhancing the informative value of measurements in surveyed pipes both longitudinally and azimuthally, thus improving the defectoscopy accuracy.

An apparatus includes a tool body and a structured illumination device attached to the tool body, wherein the structured illumination device includes a light source and a light filter mask to generate a light pattern. The apparatus also includes a subsurface camera system attached to the tool body, wherein the subsurface camera system comprises a plurality of cameras. The apparatus also includes a processor and a machine-readable medium having program code executable by the processor to cause the apparatus to acquire an image of a feature using the subsurface camera system and determine a three-dimensional position of the feature based on the image, wherein the feature is illuminated by the light pattern.

Layered coating applications for sensing telemetry are provided. An example method can include depositing an optical waveguide on an inner surface of a wellbore tool, the optical waveguide including a first layer of low refractive-index material, a second layer of high refractive-index material applied to a first surface of the first layer, and a third layer of low refractive-index material applied to a second surface of the second layer; configuring non-uniformities at one or more locations of the optical waveguide, the non-uniformities configured to reflect or scatter light at angles relative to a site of interaction between the light and the non-uniformities; determining a reflection and/or transmission pattern of light propagated through the optical waveguide and reflected or scattered by the non-uniformities; and based on the reflection and/or transmission pattern of the light, determining one or more conditions associated with of the wellbore tool.

Compositions and methods for prevention and reduction of iron sulfide scale formation, one method including detecting at least one component indicative of an iron sulfide scale precursor, the at least one component selected from the group consisting of: H.sub.2S; HS.sup.−; S.sup.2−; S.sub.n.sup.2−; FeS.sub.(aq); Fe.sup.2+; Fe.sup.3+, and combinations of the same; preparing a composition to react with the iron sulfide scale precursor, the composition comprising at least one compound selected from the group consisting of: a methylating agent; a metal operable to react with sulfide species; a compound to increase the oxidation state of Fe.sup.2+; and combinations of the same; and applying the composition to the iron sulfide scale precursor to consume the iron sulfide scale precursor.