A method for determining a real-time pore pressure log of a well in a reservoir, including the steps: storing existing data logs of surface drilling parameters, logging while drilling (LWD), and mud gas of existing wells in a database, storing existing pore pressure logs of the existing wells in the database, wherein the existing pore pressure logs correspond to the existing data logs, determining a relationship between the existing data logs and the existing pore pressure logs, drilling a new well into the reservoir, determining new data logs of surface drilling parameters, LWD, and mud gas of the new well while drilling the new well, inputting the new data logs of the new well into the relationship while drilling the new well, determining a real-time pore pressure log of the new well by outputting an estimated pore pressure at a certain depth by the relationship while drilling the new well.

A system for producing geothermal energy may include a tiered geothermal loop energy production system. The tiered geothermal loop energy production system includes: a first closed-loop pipe system emplaced within a heat-producing geologic formation, the first closed-loop pipe system having a first energy production; and a second closed-loop pipe system emplaced within a heat producing geologic formation, the second closed-loop pipe system having a second energy production greater than the first energy production; and, optionally a third closed-loop pipe system emplaced within a heat producing geologic formation, the third closed-loop pipe system having a third energy production. An energy conversion system is configured to convert energy from the tiered geothermal loop energy production system to another form of energy.

A method can include training a deep neural network to generate a trained deep neural network where the trained deep neural network represents functions of a nonlinear Kalman filter that represents a dynamic system of equipment and environment via an internal state vector of the dynamic system; generating a base internal state vector, that corresponds to a pre-defined operational procedure, using the trained deep neural network; receiving operation data from the equipment responsive to operation in the environment; generating an internal state vector using the operation data and the trained deep neural network; and comparing at least the internal state vector to at least the base internal state vector.

A horizontal drilling machine with an in-situ detection device, including a support frame, an armored cable, a steel pipe-straightening mechanism, a steel pipe-feeding mechanism, a motor, a power head, a drill pipe, a rotating chuck, a damper, a non-core drilling tool, the in-situ detection device, a fishing device and a thrust cylinder. The steel pipe-straightening mechanism, the steel pipe-feeding mechanism, the rotating chuck and the damper are sequentially fixed on the support frame from left to right. One end of the thrust cylinder is hinged with the support frame, and the other end is connected to the power head. The active drill pipe of the power head is connected to the drill pipe. An end of the armored cable is connected to the fishing device in the drill pipe, and the fishing head of the fishing device is connected to the spearhead of the non-core drilling tool.

A system, method and program product for generating an optimal field development plan (FDP) for the exploitation of oil and gas reservoirs when the available data of the reservoir is limited. A tree is generated starting from a root node wherein each node represents a decision or an observation of the field. The tree generation includes a specific manner of combining a search and a rollout process for exploring paths providing candidates of field development plans (FDP) and adding new nodes to the tree. The method reduces drastically the computational cost providing an affordable manner of estimating an optimal field development plan (FDP) before carrying out the exploitation of the reservoir.

A system can receive a combination of measurements of a drilling fluid from a wellbore during a wellbore drilling operation. The system can determine, using the combination of measurements, at least one component of the drilling fluid of the drilling fluid estimate. The system can determine, using the at least one component of the drilling fluid, a composition of the drilling fluid. The system can output the composition of the drilling fluid for use in controlling the wellbore drilling operation.

A method for optimizing drilling performance is disclosed. The method includes determining, while advancing a drill bit during a drilling operation based on drilling parameters specified by a user, a rate of penetration (ROP), acquiring, using sensors disposed on drilling equipment of a well, measurement data of each drilling equipment that represents a condition of a corresponding drilling equipment at a particular ROP during the drilling operation, determining, using an artificial intelligence method based on the measurement data, a non-linear relationship between the ROP, the drilling parameters, and the conditions of the drilling equipment, identifying a constraint specified by the user based on the conditions of the drilling equipment, determining, based on the non-linear relationship and the user specified constraint, a target value of the drilling parameters to optimize a pre-determined performance measure of the drilling operation, and further performing the drilling operation based on the target value.

An apparatus for estimating properties of an earth formation includes a carrier connected to a drilling assembly, and a sensor assembly configured to measure at least one return flow parameter of a return fluid at a surface location, the return fluid returning to the surface location from a borehole. The apparatus also includes a processor configured to perform receiving one or more return flow parameter values for a period of time after injection of fluid is stopped, analyzing the one or more return flow parameter values to identify a ballooning event, in response to identifying the ballooning event, estimating at least one of a location and a property of one or more fractures in the formation, and performing one or more aspects of at least one of the drilling operation and a subsequent operation based on at least one of the location and the property of one or more fractures.

Methods and systems for optimizing drilling operations in a wellbore using a drill string are provided. The methods and systems include measuring a first formation characteristic with at least one sensor, measuring a second formation characteristic by means of a hydraulic test, the at least one second formation characteristic being different from the at least one first formation characteristic, generating a model to represent a formation around the wellbore, the model incorporating the first formation characteristic and the second formation characteristic, and performing a drilling operation based on the generated model.

A method may include obtaining, in real-time with a drilling operation, density data regarding a drilling fluid circulating in a wellbore. The method may further include determining mud velocity data of the drilling fluid in the wellbore based on flow rate data and a borehole area of the wellbore. The method may further include determining a cuttings weight of the drilling fluid in the wellbore based on the density data. The cuttings weight and the mud velocity data may correspond to a respective segment length among various segment lengths of the wellbore. The method may further include determining, based on the cuttings weight, the mud velocity data, and a hole cleaning model, various hole cleaning efficiency (HCE) values for the segment lengths of the wellbore. The method may further include determining whether an HCE value among the HCE values fails to satisfy a predetermined criterion.