Abstract: Some methods of determining a tubing and casing annulus fluid leak of a well include receiving pressure information and depth information from three or more pressure sensors in fluid communication with a fluid of the tubing casing annulus. Some methods include receiving at least three baseline pressure gradients and determining at least three current pressure gradients based on the pressure information and depth information of the three or more pressure sensors. Some methods include determining pressure differences between the at least three baseline pressure gradients and the at least three current pressure gradients. Some methods include determining whether any of the pressure differences are above a pressure threshold, and responsive to determining that at least one of the pressure differences is above the pressure threshold, determining a fluid level of the fluid within the tubing casing annulus based on the pressure differences.

Abstract: Systems and methods include a method for optimizing maximum reservoir contact wells. For each lateral of a multi-lateral well and using input data for the lateral, a lateral flowrate is determined for each opening position for different combinations of internal control valve (ICV) sizes and target flowing bottomhole pressures. Using a numerical model, an estimated total flowrate is determined for each lateral based on the lateral's flowrate. Options are provided for presentation to a user in a user interface for changing ICV settings of the multi-lateral well. Each option includes a predicted added value to production of the multi-lateral well. The predicted added value includes one or more of an individual lateral production contribution, an enhanced sweep efficiency for one or more laterals, or a water rate reduction. A selection by the user of an option is received. The option is implemented during production of the multi-lateral well.

Abstract: Some methods of determining a tubing and casing annulus fluid leak of a well include receiving pressure information and depth information from three or more pressure sensors in fluid communication with a fluid of the tubing casing annulus. Some methods include receiving at least three baseline pressure gradients and determining at least three current pressure gradients based on the pressure information and depth information of the three or more pressure sensors. Some methods include determining pressure differences between the at least three baseline pressure gradients and the at least three current pressure gradients. Some methods include determining whether any of the pressure differences are above a pressure threshold, and responsive to determining that at least one of the pressure differences is above the pressure threshold, determining a fluid level of the fluid within the tubing casing annulus based on the pressure differences.

Abstract: Systems and methods include a method for optimizing maximum reservoir contact wells. For each lateral of a multi-lateral well and using input data for the lateral, a lateral flowrate is determined for each opening position for different combinations of internal control valve (ICV) sizes and target flowing bottomhole pressures. Using a numerical model, an estimated total flowrate is determined for each lateral based on the lateral's flowrate. Options are provided for presentation to a user in a user interface for changing ICV settings of the multi-lateral well. Each option includes a predicted added value to production of the multi-lateral well. The predicted added value includes one or more of an individual lateral production contribution, an enhanced sweep efficiency for one or more laterals, or a water rate reduction. A selection by the user of an option is received. The option is implemented during production of the multi-lateral well.