Abstract: Methods and systems for monitoring an annulus pressure of a well. The method includes performing periodic surveys to monitor an annulus pressure of the well, determining the annulus pressure of the well over a period of time, comparing the annulus pressure to a Maximum Allowable Wellhead Operating Pressure (MAWOP), and generating a decision on whether the well is a workover candidate based on results of the comparison. The system includes a collecting tool that performs periodic surveys to monitor an annulus pressure of the well, determines the annulus pressure of the well over a period of time, and broadcasts information relating to the periodic surveys. The system further includes a processor that obtains the information relating the periodic surveys, compares the annulus pressure to a Maximum Allowable Wellhead Operating Pressure (MAWOP), and generates a decision on whether the well is a workover candidate based on the results of the comparison.

Abstract: Disclosed are methods, systems, and computer-readable medium to perform operations including: generating, based on production data for a wellbore, (i) a water-oil-ratio with respect to time (WOR) dataset for the wellbore, (ii) a time-derivative dataset (WOR?) of the WOR dataset; generating a WOR log-log plot of the WOR dataset and a WOR? log-log plot of the WOR? dataset; identifying at least one trend in the WOR log-log plot and the WOR? log-log plot; determining, based on the at least one identified trend, a first type of water breakthrough; generating, based on pressure data from a build-up pressure test in the wellbore, a log-log plot of time-derivative pressure data with respect to time (P?); determining, based on the P? log-log plot, a second type of water breakthrough; correlating the first and second type of water breakthrough; and determining, based on the correlation, whether to perform a water treatment for the wellbore.

Abstract: The present disclosure describes a method that includes: accessing production logs at a well location of the carbonate reservoir, the production logs comprising data encoding a flow meter profile and a ratio of water and oil (WOR) at each depth of a range of depths; accessing measurements of core samples extracted from each depth within the range of depths; based on the measurements of core samples, determining a relationship of permeability and porosity at each depth within the range of depths; based on the production logs, analyzing the WOR to determine a derivative WOR? (dWOR/dt) at each depth within the range of depths; and characterizing at least one productive zone at the well location based on a combination of the WOR, the WOR?, the flow meter profile, and the relationship of permeability and porosity at each depth within the range of depths.

Abstract: A system includes an upper sheave configured to orient a cable towards a well, a lower sheave, having a center, configured to orient the cable towards the upper sheave, and a sheave stand. The sheave stand includes a shaft, running through the center of the lower sheave, configured to enable rotation of the lower sheave about a central axis, a sheave holder, fixed to the shaft, configured to hold the lower sheave in a vertical position, a tool leg, fixed to the shaft, configured to elevate the shaft to a height above a surface, and a floor stand, fixed to the tool leg, configured to anchor the sheave stand to the surface. The sheave stand stabilizes the cable by maintaining the lower sheave in a fixed rotational position.

Abstract: Methods and systems for monitoring an annulus pressure of a well. The method includes performing periodic surveys to monitor an annulus pressure of the well, determining the annulus pressure of the well over a period of time, comparing the annulus pressure to a Maximum Allowable Wellhead Operating Pressure (MAWOP), and generating a decision on whether the well is a workover candidate based on results of the comparison. The system includes a collecting tool that performs periodic surveys to monitor an annulus pressure of the well, determines the annulus pressure of the well over a period of time, and broadcasts information relating to the periodic surveys. The system further includes a processor that obtains the information relating the periodic surveys, compares the annulus pressure to a Maximum Allowable Wellhead Operating Pressure (MAWOP), and generates a decision on whether the well is a workover candidate based on the results of the comparison.

Abstract: A method of determining a presence of a leak in a wall of a production tubing string includes positioning an electrical submersible pump is positioned at the string's downhole end. Based on measurements from a pressure sensor positioned at a downhole location at a discharge end of the electrical submersible pump, it is determined that a discharge pressure has decreased over a specified time period. Based on measurements from a pressure sensor within a wellhead of the well, it is determined that a pressure within the production tubing string at the surface has decreased over the specified time period. Based on measurements from a flow-rate sensor at an uphole end of the production tubing string, it is determined the flow rate has decreased relative to a calculated expected flow rate. Based on a pressure integrity test initiated in response to these determinations, the presence of the leak is determined.

Abstract: A method for well integrity management on a well having at least one surface valve and a surface controlled sub-surface safety valve includes closing the at least one surface valve, applying a predetermined pressure to the at least one surface valve, analyzing a pressure loss across the at least one surface valve, and testing the surface controlled sub-surface safety valve for functionality. Functionality testing of the surface controlled sub-surface safety valve includes opening and closing the surface controlled sub-surface safety valve using a control panel. The method further includes classifying the well as operable or inoperable based on the pressure loss across the at least one surface valve and the functionality of the surface controlled sub-surface safety valve.

Abstract: Systems and methods include a computer-implemented method for determining an integrated surface-downhole integrity score for a natural flow oil well. Wellness surface parameters of a natural flow oil well are determined. Wellness downhole parameters for the natural flow oil well are determined, including parameters indicating well integrity and tubing/casing conditions. An integrated surface-downhole integrity score is determined using the wellness surface parameters and the wellness downhole parameters. An alert is provided for presentation to an operator in a user interface. The alert is provided in response to the integrated surface-downhole integrity score exceeding a threshold.

Abstract: Systems and methods include a computer-implemented method for determining an integrated surface-downhole integrity score for Christmas tree and wellhead assembly valves of an electrical submersible pump (ESP) oil well. Wellness surface parameters are determined for an ESP oil well operating at least one ESP. Wellness downhole parameters are determined for the oil well, including parameters indicating well integrity and pump efficiency. An integrated surface-downhole integrity score is determined using the wellness surface parameters and the wellness downhole parameters. The integrated surface-downhole integrity score indicates an integrated integrity of Christmas tree and wellhead assembly valves for the ESP oil well. An alert is provided in response to determining that the integrated surface-downhole integrity score exceeds a threshold. The alert is provided for presentation to an operator in a user interface.

Abstract: The present disclosure describes a method that includes: accessing production logs at a well location of the carbonate reservoir, the production logs comprising data encoding a flow meter profile and a ratio of water and oil (WOR) at each depth of a range of depths; accessing measurements of core samples extracted from each depth within the range of depths; based on the measurements of core samples, determining a relationship of permeability and porosity at each depth within the range of depths; based on the production logs, analyzing the WOR to determine a derivative WOR? (dWOR/dt) at each depth within the range of depths; and characterizing at least one productive zone at the well location based on a combination of the WOR, the WOR?, the flow meter profile, and the relationship of permeability and porosity at each depth within the range of depths.

Abstract: Disclosed are methods, systems, and computer-readable medium to perform operations including: generating, based on production data for a wellbore, (i) a water-oil-ratio with respect to time (WOR) dataset for the wellbore, (ii) a time-derivative dataset (WOR?) of the WOR dataset; generating a WOR log-log plot of the WOR dataset and a WOR? log-log plot of the WOR? dataset; identifying at least one trend in the WOR log-log plot and the WOR? log-log plot; determining, based on the at least one identified trend, a first type of water breakthrough; generating, based on pressure data from a build-up pressure test in the wellbore, a log-log plot of time-derivative pressure data with respect to time (P?); determining, based on the P? log-log plot, a second type of water breakthrough; correlating the first and second type of water breakthrough; and determining, based on the correlation, whether to perform a water treatment for the wellbore.

Abstract: Provided is a method for treating a sandstone formation with a well treatment composition. The method may include introducing a pre-flush pill, introducing the well treatment composition, introducing a post-flush fluid, and maintaining the wellbore such that the well treatment composition interacts with the sandstone formation. Further provided is a method that may introduce the well treatment composition as two pills, such as an organic acid pill and an inorganic acid pill. The well treatment composition may include an aqueous solution of an ammonium salt, an inorganic acid, an organic acid, and optionally one or more of a pH adjuster, a mutual solvent, a surfactant, and a corrosion inhibitor.

Abstract: Provided is a method for treating a sandstone formation with a well treatment composition. The method may include introducing a pre-flush pill, introducing the well treatment composition, introducing a post-flush fluid, and maintaining the wellbore such that the well treatment composition interacts with the sandstone formation. Further provided is a method that may introduce the well treatment composition as two pills, such as an organic acid pill and an inorganic acid pill. The well treatment composition may include an aqueous solution of an ammonium salt, an inorganic acid, an organic acid, and optionally one or more of a pH adjuster, a mutual solvent, a surfactant, and a corrosion inhibitor.

Abstract: A system includes an upper sheave configured to orient a cable towards a well, a lower sheave, having a center, configured to orient the cable towards the upper sheave, and a sheave stand. The sheave stand includes a shaft, running through the center of the lower sheave, configured to enable rotation of the lower sheave about a central axis, a sheave holder, fixed to the shaft, configured to hold the lower sheave in a vertical position, a tool leg, fixed to the shaft, configured to elevate the shaft to a height above a surface, and a floor stand, fixed to the tool leg, configured to anchor the sheave stand to the surface. The sheave stand stabilizes the cable by maintaining the lower sheave in a fixed rotational position.

Abstract: Compositions and methods for plugging a zone of a subterranean formation includes a cement composition having an acid soluble cement, a low molecular weight polymer, a high molecular weight polymer, and water. The acid soluble cement is in amount in a range of 10% to 50% by weight of the composition.

Abstract: A method of determining a presence of a leak in a wall of a production tubing string includes positioning an electrical submersible pump is positioned at the string's downhole end. Based on measurements from a pressure sensor positioned at a downhole location at a discharge end of the electrical submersible pump, it is determined that a discharge pressure has decreased over a specified time period. Based on measurements from a pressure sensor within a wellhead of the well, it is determined that a pressure within the production tubing string at the surface has decreased over the specified time period. Based on measurements from a flow-rate sensor at an uphole end of the production tubing string, it is determined the flow rate has decreased relative to a calculated expected flow rate. Based on a pressure integrity test initiated in response to these determinations, the presence of the leak is determined.

Abstract: Compositions and methods for plugging a zone of a subterranean formation includes a cement composition having an acid soluble cement, a low molecular weight polymer, a high molecular weight polymer, and water. The acid soluble cement is in amount in a range of 10% to 50% by weight of the composition.

Abstract: An apparatus and process for testing a sample of a hydraulic fracturing fluid is provided. A small quantity of a fracturing fluid sample to be observed and/or tested is placed in a chamber designed with suitable heat and pressure simulation apparatus. With the sample chamber, the efficacy of the fracturing fluid can be ascertained, improper fracturing fluid compositions and/or mixtures, e.g., caused by human error, can be detected, and contamination of the frac-tank can be determined. The overall apparatus is portable and can be transported to the site of the fracturing fluid tank, thereby allowing testing immediately prior to introduction into the well. The samples in the test chamber can be observed for quality control and quality assurance prior to, or during stimulation and water shutoff treatments in the field.

Abstract: An apparatus and process for testing a sample of a hydraulic fracturing fluid is provided. A small quantity of a fracturing fluid sample to be observed and/or tested is placed in a chamber designed with suitable heat and pressure simulation apparatus. With the sample chamber, the efficacy of the fracturing fluid can be ascertained, improper fracturing fluid compositions and/or mixtures, e.g., caused by human error, can be detected, and contamination of the frac-tank can be determined. The overall apparatus is portable and can be transported to the site of the fracturing fluid tank, thereby allowing testing immediately prior to introduction into the well. The samples in the test chamber can be observed for quality control and quality assurance prior to, or during stimulation and water shutoff treatments in the field.

Abstract: A method and a composition for stimulating oil production from wells which have ceased production by pumping in a mixture of gluconic, oxalic and citric acids, isopropanol, ethylene glycol and sodium citrate between pre-flush and over-flush intervals, which composition and method does not include the use of hydrochloric acid or hydrofluoric acid.