A method for producing a well includes receiving production information associated with wells within a field; deriving a field specific model from the production information; receiving production information associated with the well; projecting production changes associated with installing artificial lift at the well at a projected date, the projecting using a production analysis engine applied to the field specific model, the projecting including determining a set of artificial lift parameters; and installing the artificial lift at the well in accordance with the artificial lift parameters.

A system can identify a type of contamination for drilling fluid based on measured fluid properties of the drilling fluid and fluid properties of a reference drilling fluid. A system can measure a first plurality of fluid properties for a drilling fluid sample contaminated from a wellbore drilling operation. A system can select a predicted model in relation to one or more types of contamination by comparing the first plurality of fluid properties and a second plurality of fluid properties measured from a reference fluid sample. A system can analyze the first plurality of fluid properties and a third plurality of fluid properties generated from the predicted model to determine a first type of contamination in the drilling fluid sample.

A method and system method for determining motion of a downhole tool and feeding back drilling performance. The method may comprise taking a synchronous tool face measurement of the downhole tool, taking a synchronous pulse-echo acquisition to estimate a shape of a borehole, inputting at least the shape of the borehole, the center trajectory of the downhole tool, the rotational time of the downhole tool, the position of the downhole tool, and the one or more measurements of the downhole tool into an information fusion for drilling dynamics, identifying at least one of a whirl, a vibration, or a stick-slip of the downhole tool, and identifying one or more borehole condition and a drilling efficiency. A system may comprise a downhole tool, at least two transducers, and an information handling system.

A system includes a sensor carrier and an integrated data recorder. The sensor carrier includes an outer sub body and an inner sub body. The inner sub body is coupled to the outer sub body by a support leg. The inner sub body includes a recess formed therein. The sensor carrier includes a flow path defined as the space between the outer sub body, the inner sub body, and the support leg. The integrated data recorder is positioned within the recess of the inner sub body such that the integrated data recorder is substantially at the centerline of the sensor carrier. The integrated data recorder includes a sensor package including one or more drilling dynamics sensors, a processor, a memory module, and an electrical energy source.

The invention discloses a drill bit design method based on rock crushing principle with local variable strength, including: drill bit is divided into local crushing feature regions; strength mode factors of the local crushing feature regions are calculated; a difference among strength mode factors of the local crushing feature regions is obtained to obtain a vector sum of horizontal cutting forces of the drill bit tooth corresponding to the same group of cutting tooth on the drill bit; treating the difference among the strength mode factors of the local crushing feature region as a target control condition for drill bit design. Based on the rock crushing principle with local variable strength, after dividing the symmetrical cutting tooth into groups, the strength variation factors of the symmetrical position are adjusted and balanced, so that the rock crushing strength of different local crushing feature regions can be changed in a targeted manner.

A system for adapting drilling of a borehole in a subterranean formation based on comparing a received cuttings weight to an expected cuttings weight. The system comprises a processor; a non-transitory memory; at least one display; and an application stored in the non-transitory memory that, when executed by the processor, determines the received cuttings weight based on data received from a cuttings storage unit (CSU); determines the expected cuttings weight based on a current borehole depth, on a drill bit geometry, and on a cuttings density value; and presents a representation of the received cuttings weight and a representation of the expected cuttings weight on the at least one display, whereby at least one parameter of drilling of the borehole is adapted based on comparing the representation of the received cuttings to the representation of the expected cuttings weight.

Various embodiments include apparatus and methods to estimate properties of rock, drill bit, or a combination thereof associated with a drilling operation. The properties can include, but are not limited to, rock chip size, drill bit dullness, drilling efficiency, or a combination selected from rock chip size, drill bit dullness, and drilling efficiency. The estimate may be accomplished from correlating detected acoustic emission with detected electromagnetic emissions. In various embodiments, formation brittleness may be determined. The various estimates may be used to direct a drilling operation. Additional apparatus, systems, and methods are disclosed.

A method can include receiving channels of data from equipment responsive to operation of the equipment in an environment where the equipment and environment form a dynamic system; defining a particle filter that localizes a time window with respect to the channels of data; applying the particle filter at least in part by weighting particles of the particle filter using the channels of data, where each of the particles represents a corresponding time window; and selecting one of the particles according to its weight as being the time window of an operational state of the dynamic system.

Provided in the present invention a method for evaluating the mixing effect of a CO.sub.2 oil-displacing and mixing agent, characterized in measuring the volume expansion of a CO.sub.2-oil interface when pressure is gradually increased, drawing a mixed-phase percentage-pressure curve (δ-P curve), and evaluating the mixing effect of the CO.sub.2 oil-displacing and mixing agent by means of comparing the characteristics of the δ-P curve. Further provided in the present invention is a method for initially screening a CO.sub.2 oil-displacing and mixing agent.

A computer-implemented method for providing a performance parameter value indicative of a production performance of a first floating hydrocarbon production plant. The first plant includes hydrocarbon processing equipment and a sensor for measuring a value of a process parameter of the hydrocarbon processing equipment. The method includes obtaining first plant data from the first plant, the data including data generated by the sensor, obtaining a trained predictive model for predicting or classifying the performance parameter value, and providing, based on the trained predictive model and the first plant data, the performance parameter value for the first plant. Obtaining the trained predictive model includes obtaining plant training data from a second floating hydrocarbon production plant, the data including data generated by a sensor for measuring a process parameter value of hydrocarbon processing equipment of the second plant, providing a predictive model, and training the predictive model using the plant training data.