Abstract: A well system includes a wellbore penetrating a subterranean formation, production tubing extended into the wellbore and terminating at a completion string, and one or more inflow control devices forming part of the completion string. The inflow control device includes a base pipe defining one or more first flow ports and one or more second flow ports axially spaced from the first flow ports. A first flow regulation device is arranged within the base pipe and actuatable to expose or occlude the first flow ports, and a second flow regulation device is arranged within the base pipe and actuatable to expose or occlude the second flow ports. A downhole shifting device is operable to independently manipulate a position of the first and second flow regulation devices and thereby selectively expose or occlude the first or second flow ports.

Abstract: A well completion includes a production tubing and a well tool. The production tubing includes an elongate cylindrical body including an inner diameter and having a length. The production tubing includes a completion profile formed at a location along the length of the body. An inner diameter of the completion profile is equal to an inner diameter of the body. The well tool is attached to the completion profile.

Abstract: An apparatus for obtaining fluids via a well includes an outer tubing disposed in the well and set at a shallow reservoir comprising a first fluid, and an inner tubing disposed concentrically within the outer tubing and set at a deeper reservoir further downhole than the shallow reservoir. The deeper reservoir has a second fluid, where a first packer is disposed between the outer tubing and an external tubing and disposed above the shallow reservoir, and a second packer is disposed between the outer tubing and the inner tubing and disposed above the deeper reservoir. The second packer blocks an annulus through which the first fluid is extracted via the outer tubing. The first fluid is obtained from the shallow reservoir and the second fluid is obtained from the deeper reservoir by drilling via the well.

Abstract: Techniques for developing a hydrocarbon well that include: determining a skin increase threshold; collecting historical production data for hydrocarbon wells; determining, based on the data, skin profiles for the wells; identifying, in response to changes in skin that exceed the threshold, wells as candidates for stimulation; for each of the candidate wells: determining an observed production rate; determining a predicted production rate that corresponds to a skin of zero; determining a cost of stimulation to remediate the well; determining, based on the observed and predicted production rates, a predicted increase in production attributable to stimulation; and determining, based on the cost of stimulation and the predicted increase, a marginal production cost for increased production; selecting, based on the marginal production costs of the candidate wells, a well to be stimulated; and conducting a stimulation of the well selected.

Abstract: An apparatus for obtaining fluids via a well is disclosed. The apparatus includes an outer tubing disposed in the well and set at a shallow reservoir comprising a first fluid, an inner tubing disposed concentrically within the outer tubing and set at a deeper reservoir further downhole than the shallow reservoir, the deeper reservoir comprising a second fluid, a first packer disposed between the outer tubing and an external tubing and disposed above the shallow reservoir, and a second packer disposed between the outer tubing and the inner tubing and disposed above the deeper reservoir, wherein the second packer blocks an annulus through which the first fluid is extracted via the outer tubing. The first fluid is obtained from the shallow reservoir and the second fluid is obtained from the deeper reservoir by drilling via the well.

Abstract: The check valve positioned within a production tubing string is configured to open when a differential pressure across the check valve exceeds a specified opening differential pressure. With the check valve closed, a specified volume of gas is flowed from the production tubing string, thereby decreasing the pressure within the production tubing string from a first wellhead pressure to a second, lesser wellhead pressure. Hydrostatic pressure within the production tubing string at the check valve is increased by flowing a specified volume of water into the production tubing string above the check valve to at least partially replace the specified volume of gas. After flowing the water, a specified volume of treatment fluid is injected into the production tubing string at an injection pressure less than the first wellhead pressure and greater than the second wellhead pressure, thereby opening the check valve and flowing the treatment fluid downhole.

Abstract: Systems and methods include a computer-implemented method for selecting well candidates. Pre- and post-stimulation production rates are determined for initial stimulation job candidates of an oil well. A field performance decline factor is determined as an average slope of post-job monthly rate changes for each well determined using a performance decline equation. A time period that a stimulated well will reach its pre-stimulation oil production rate is determined. The performance decline equation is re-executed until a future additional production rate gain approaches zero. A monthly additional production rate is determined based on the field performance decline factor, and a cumulative additional production rate for each candidate is determined. A best candidate is determined based on comparing the cumulative additional production rate for each candidate.

Abstract: A pressure bleed-off module for an oil well includes: an inlet receiving fluid from an annulus vent of the well; an outlet sending the received fluid to a kill valve of the well; and two paths coupled in parallel between the inlet and the outlet. Each path channels a flow of the received fluid from the inlet to the outlet and includes: a pressure relief valve dividing the path into an inlet side coupled to the inlet and an outlet side coupled to the outlet, opening when the pressure of the fluid in the inlet side exceeds a threshold, and closing when the inlet fluid pressure is below the threshold; pressure gauges measuring the inlet fluid pressure and the pressure of the fluid in the outlet side; a pressure recorder recording the measured inlet and outlet fluid pressures; and a sampling point for draining the fluid in the outlet side.

Abstract: Provided are techniques that include determining a first set of operating parameters for a hydrocarbon well for a first period; determining, based on the first set of operating parameters, a skin factor (S1); determining, based on the skin factor (S1), a well model for the well; determining, a second set of operating parameters for the well for a second period; determining, based on the second set of operating parameters, well performance characteristics for the second period that include: a well pressure and a production flowrate for the second period of time; determining that the well performance characteristics for the second period are not consistent with the well model and, in response: determining, based on the second set of operating parameters, an updated skin factor; and determining, based on the updated skin factor (S2), an updated well model for the well.

Abstract: Techniques for developing a hydrocarbon well that include: determining a skin increase threshold; collecting historical production data for hydrocarbon wells; determining, based on the data, skin profiles for the wells; identifying, in response to changes in skin that exceed the threshold, wells as candidates for stimulation; for each of the candidate wells: determining an observed production rate; determining a predicted production rate that corresponds to a skin of zero; determining a cost of stimulation to remediate the well; determining, based on the observed and predicted production rates, a predicted increase in production attributable to stimulation; and determining, based on the cost of stimulation and the predicted increase, a marginal production cost for increased production; selecting, based on the marginal production costs of the candidate wells, a well to be stimulated; and conducting a stimulation of the well selected.

Abstract: A pressure bleed-off module for an oil well includes: an inlet receiving fluid from an annulus vent of the well; an outlet sending the received fluid to a kill valve of the well; and two paths coupled in parallel between the inlet and the outlet. Each path channels a flow of the received fluid from the inlet to the outlet and includes: a pressure relief valve dividing the path into an inlet side coupled to the inlet and an outlet side coupled to the outlet, opening when the pressure of the fluid in the inlet side exceeds a threshold, and closing when the inlet fluid pressure is below the threshold; pressure gauges measuring the inlet fluid pressure and the pressure of the fluid in the outlet side; a pressure recorder recording the measured inlet and outlet fluid pressures; and a sampling point for draining the fluid in the outlet side.

Abstract: Provided are techniques that include determining a first set of operating parameters for a hydrocarbon well for a first period; determining, based on the first set of operating parameters, a skin factor (S1); determining, based on the skin factor (S1), a well model for the well; determining, a second set of operating parameters for the well for a second period; determining, based on the second set of operating parameters, well performance characteristics for the second period that include: a well pressure and a production flowrate for the second period of time; determining that the well performance characteristics for the second period are not consistent with the well model and, in response: determining, based on the second set of operating parameters, an updated skin factor; and determining, based on the updated skin factor (S2), an updated well model for the well.