Saudi Arabian Oil Company

James Ohioma Arukhe

Ammal F Al-Anazi

Torty Chinenye Kalu-Ulu

Ali Naji Alaithan

Obiomalotaoso Leonard Isichei

Hamad Al-Marri

Wail Khalid Aljehani

Emeka Agbo

Mohannad Abo Khamseen

Mohammed H Aleid

Jaafar Sawad

Faisal Khelaiwi

Rayed Mohammed Al-Zayer

Fahad Altwimi

Ammal Fannoush Al-anazi

Mohammed A Nasr

Shearable lift gas valves ('SLG valves') are installed in a well and operate on a contingency basis for injecting lift gas into the well; such as when a lift gas valve that has been in service becomes inoperable or inefficient, or changed well conditions necessitate some form of artificial lift. The SLG valves are maintained in a non-activated configuration with an inner retaining element, and are activated by applying a designated pressure that fractures the retaining element; when activated, the SLG valves operate like other automatic lift gas valves. A SLG valve is installed at a set pressure to replace the inoperable lift gas valve, or at a set pressure that anticipates a change in well conditions, so that when activated, the SLG valve functions at a set pressure different from an in service lift gas valve, and optimizes production from the well with the changed conditions.

Gas lift system with shearable lift gas valves

A method to perform zonal inflow analysis of a well. The method includes disposing a chemical tracer module in each perforation zone in the well to interact with produced fluid to produce a zonal signature that uniquely identifies the corresponding perforation zone, obtaining a production flow at a wellhead that has zonal contributions of the produced fluid from the perforation zones, measuring, in the production flow and using a chemical analysis panel at the Earth's surface, a concentration of the zonal signature of each perforation zone, determining, using at least the chemical analysis panel and based on the concentration of the zonal signature of each perforation zone, a respective measure of each zonal contribution, and facilitating, based on the respective measure of each zonal contribution, a production operation of the well.

Real-time zonal inflow analyzer with closed-loop tracer system

A system and method for deploying and retrieving a welltracker in a well include coupling a Christmas tree to the well, coupling a sensor deployment capsule to the Christmas tree, inserting and storing the welltracker into the cylindrical housing via a removable cap screw, and deploying the welltracker through the Christmas tree and into the well. The system and method further include dissolving a dissolvable weight on the welltracker at a well fluid pressure threshold, retrieving the welltracker to the cylindrical housing, bleeding off trapped pressure in the cylindrical housing from retrieval, via the drain valve, through the pressure transfer line, and controlling pressure in the sensor deployment capsule via the pressure gauge. The sensor deployment capsule includes a cylindrical housing including a removable cap screw, a drain valve coupled to the cylindrical housing and a pressure transfer line, and a pressure gauge coupled to the removable cap screw.

Advanced welltracker deployment capsule for oil and gas wells

A system performs rig-less well intervention at wellbore. The system includes a wellhead provided at a wellbore and a flow regulation device that selectively admits a flow of formation fluid between the wellhead and the blowout preventer. The system further includes a shifting tool mechanism configured to latch on and engage the flow regulation device to selectively control the flow of formation fluid between the wellhead and the blowout preventer. A related method includes connecting a rig-less well intervention unit to a blowout preventer and connecting the blowout preventer to a Christmas tree. The blowout preventer comprises a shifting tool mechanism and the Christmas tree comprises a flow regulation device. The method further includes lowering the shifting tool mechanism to a predetermined depth, engaging the shifting tool mechanism with the flow regulation device and activating the shifting tool mechanism to actuate the flow regulation device to an open position.

Integrated valve blowout preventer for rig-less well interventions

A system and method for a probe protector in a well includes a cable disposed within the well; a probe installed on an end of the cable; and a probe protector mounted on the cable conductor. The probe includes at least one lead and a cable conductor disposed on a distal end of each of the at least one lead. The probe protector is removably connected over the cable conductor. The probe protector is removed from the cable conductor prior to insertion of the cable into the well.

Electrical submersible pump (ESP) landing test probe protection design

A surface safety valve for a well system includes a main valve body with a central bore through it. The main valve body has a centerline axis and is configured to be connected at a surface location above a surface of the Earth to a surface assembly of the well system and to receive through the central bore a flow of wellbore fluid from a subterranean zone conveyed by a production tubing. A gate is positioned within the main valve body and is configured to move from an open position in which the gate does not block flow of wellbore fluid through the central bore to a closed position in which the gate blocks flow of wellbore fluid through the central bore. The gate travels from the open position to the closed position along a gate movement axis perpendicular to the centerline bore axis. The gate includes a gate front end positioned on a first side of the centerline bore axis and a gate back end positioned on a second side of the centerline bore axis opposite the first side. The surface safety valve also includes an actuator positioned on the first side of the centerline bore axis. The actuator is configured to selectively push the gate towards the open position. The safety valve also includes a spring enclosed within the main valve body and positioned on the second side of the centerline bore axis. The spring is connected to the gate back end and is configured to bias the gate towards the closed position.

Surface safety valve

Measurement data including data of a sand production rate from a sand metering sensor, pressure data from a pressure sensor, and data of a metal loss value from a metal loss sensor is obtained. A maximum sand erosional velocity ratio and a pressure drawdown are determined. An optimum choke valve setting is determined based on a predefined correlation between the sand production rate, the pressure drawdown, and the maximum sand erosional velocity ratio, in response to determining that the maximum sand erosional velocity ratio is not within a predetermined maximum sand erosional velocity ratio limit. An updated pressure drawdown produced by the determined optimum choke valve setting is within a predetermined pressure drawdown operating window. The surface choke valve is set based on the determined optimum choke valve setting. The well is shutdown by triggering an emergency shutdown device in response to determining that the obtained metal loss value has reached a predefined metal loss limit value.

Integrated system and method for automated monitoring and control of sand-prone well

Techniques for managing water disposal include circulating a mixed water-oil liquid in a pipeline from a water-oil separation plant toward at least one disposal well that includes a wellbore formed from a terranean surface to a subterranean formation; determining, based on a sampling of the mixed water-oil liquid by an OIW meter, an amount of oil in the mixed water-oil liquid; based on the amount of oil being within a desired amount range: controlling each a choke valve and a surface safety valve to modulate toward an open position, and controlling a recycle valve to modulate to a closed position; and based on the amount of oil being outside of the desired amount range: controlling the choke valve and the surface safety valve to modulate toward a closed position, and controlling the recycle valve to modulate to an open position.

Managing water injected into a disposal well

A well livening system to reduce an accumulation in a wellbore includes a chemical skid, the chemical skid includes a chemical storage tank configured to contain the dosing chemical, a dosing pump configured to transfer an amount of the dosing chemical from the chemical storage tank to a wellbore, a skid line, and a dosing check valve configured to allow flow of the amount of dosing chemical, a controller system configured to determine the amount of dosing chemical to be transferred to the wellbore based on downhole data, the connection line configured to transport the amount of dosing chemical from the chemical skid, an injection spool, a hanger configured to support the chemical injection string and to isolate the wellbore from the surface, the chemical injection string configured to deliver the amount of dosing chemical to the wellbore, and a data acquisition system configured to collect downhole data.

Systems and methods to chemically liven dead wells

A turbine-powered electrical submersible pump (ESP) that has intake and discharge ports. The ESP intakes wellbore fluid from the intake port at an intake pressure, pressurizes the fluid, and discharges the fluid from the discharge port at a discharge pressure higher than the intake pressure. A motor is coupled to and drives the ESP. A turbine generator has a flow passage disposed between turbine intake and discharge ports. The turbine intake port is fluidly coupled to the pump discharge port. The turbine generator generates electric power from the pressurized wellbore fluid flowing through the flow passage and is electrically coupled to the motor and powers the motor with the generated electric power. A rechargeable battery is electrically coupled to the motor and provides power to initially start the motor. The turbine generator is further electrically coupled to the battery and recharges the battery.

Turbine powered electrical submersible pump system

Provided are techniques for operating a hydrocarbon well having inflow control valves (ICVs) and an electrical submersible pump (ESP) disposed in a wellbore of the well. Baseline production data is acquired for a relatively small subset of the possible operating configurations of ICVs in the well, the baseline data is assessed to model fluid pressure gradients in the wellbore, and the modeled fluid pressure gradients are used to estimate an ESP intake pressure for one or more configurations of the ICVs, and the ICVs are controlled to operate in accordance with an ICV configuration associated with an estimated ESP intake pressure that is within an operating intake pressure range for the ESP.

Growing community of inventors

Dhahran, Saudi Arabia

James Ohioma Arukhe