The present invention discloses an optimization design method for volumetric fracturing construction parameters of an infilled well of an unconventional oil and gas reservoir. The method comprises the following steps: S1, establishing a three-dimensional geological model with physical and geomechanical parameters; S2, establishing a natural fracture network model through integration of rock core-logging-seismic data; S3, generating old well hydraulic fracturing complex fractures based on the natural crack model; S4. establishing a three-dimensional shale gas reservoir seepage model; S5, establishing a three-dimensional geomechanical model; S6, analyzing and calculating a dynamic geostress field; S7, establishing a numerical model for horizontal fracturing complex fractures in the infilled well based on the calculation results of old well complex fractures and dynamic geostress; and S8, performing optimization design on volumetric fracturing construction parameters of the infilled well. The method of the present invention has the following beneficial effects: the effects of long-term exploitation of shale reservoirs in which natural fractures are developed on volumetric fracturing of the infilled well can be reflected accurately, the fracturing construction parameters are subjected to optimization design, the fracturing effect is improved effectively, and the single-well capacity is increased.

A method for determining a favorable time window of an infill well of an unconventional oil and gas reservoir, which comprises the following steps: S1, establishing a three-dimensional geological model with physical properties and geomechanical parameters; S2, establishing a natural fracture network model in combination with indoor core-logging-seismic monitoring; S3, calculating complex fractures in hydraulic fracturing of parent wells; S4, establishing an unconventional oil and gas reservoir model and calculating a current pore pressure field; S5, establishing a dynamic geomechanical model and calculating a dynamic geostress field; S6, calculating complex fractures in horizontal fractures of the infill well in different production times of the parent wells based on pre-stage complex fractures and the current geostress field; S7, analyzing a microseismic event barrier region and its dynamic changes in infill well fracturing; and S8, analyzing the productivity in different infill times, and determining an infill time window.

Wavelet estimation may be performed in a reservoir simulation model that is constrained by seismic inversion data and well logs. A synthetic seismic trace is generated along with an estimated wavelet. The reservoir simulation model is revised based on results from model comparisons to actual data or base seismic data and is then used to perform a wavelet estimation. The estimated wavelet may then be used to plan further production at the well site environment, additional production at additional well site environments or any other production and drilling operation for any given present or future well site environment.

The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for determining a mudweight of drilling fluids in a hydrocarbon reservoir. One computer-implemented method includes: receiving pore pressure data of a rock formation in the hydrocarbon reservoir; determining permeability data of fractures of the hydrocarbon reservoir; determining Hoek-Brown failure criterion data; and determining a safe mudweight window based on the pore pressure data of the rock formation, the permeability data of the fractures, and the Hoek-Brown failure criterion data.

The invention is a method for exploiting a subterranean formation including hydrocarbons with at least one lithologic facies of the formation having undergone at least one diagenetic phase over geological times. From at least one sample of rock obtained from the formation, from measured production data relating to the formation and from a meshed representation representative of the formation, each mesh of the meshed representation is determined including at least one indicator relating to the distribution of the facies present in the mesh. The method comprises a step of history matching in which at least one of the adjustment parameters is the diagenetic state of the identified facies.

Techniques for controlling a hydrocarbon production system include determining a first estimate of a prior FVC detectability probability map based on a plurality of reservoir data that includes four-dimensional (4D) seismic data of a subterranean reservoir; determining a second estimate of the prior FVC detectability probability map under seismic data noise conditions; determining an updated detectable FVC probability based on the 4D seismic data; determining an updated FVC probability based on the updated detectable FVC probability and the first and second estimates of the prior FVC detectability probability maps; and generating a control instruction for at least one of a fluid injection system or a hydrocarbon production assembly based on the updated FVC probability.

A method of performing oilfield operations at a wellsite is disclosed. The wellsite is positioned about a subterranean formation having multiple wellbores therethrough and a fracture network therein. The fracture network includes natural fractures. The method involves generating fracture parameters including a hydraulic fracture network of a fracture grid for each of the multiple wellbores based on wellsite data including microseismic events and a mechanical earth model, generating reservoir parameters including an updated mechanical earth model of a reservoir grid based on the wellsite data and the fracture parameters, generating integrated wellsite parameters including an integrated earth model by integrating the fracture parameters from the multiple wellbores with the reservoir parameters, and performing production operations at the multiple wellbores based on the integrated wellsite parameters.

Methods and an alarming system for long-term carbon dioxide sequestration in a geologic reservoir are described. The geologic reservoir may be a water filled sandstone reservoir or a carbonate reservoir. A reservoir model is constructed to show the effects of varying injection pressures, the number of injection wells, the arrangement of injection wells, the boundary conditions and sizes of the reservoir on caprock uplift, fracture formation and fracture reactivation. The alarming system generates an alarm when caprock uplift that surpasses a threshold is detected. The injection pressures and the number of injection wells operating may be varied in response to the alarm.

Provided are systems and method for computed resource hydrocarbon reservoir simulation that include, after processing the domain of a model to a point sufficient to determine an initial set of domain decomposition (DD) characteristics (for example, after preliminary grid calculations and initial DD operations), determining the DD characteristics of the initial DD, comparing the DD characteristics to a domain target defined by target DD parameters, and if needed, iteratively repartitioning the domain across a decreasing number of processors and reshuffling the associated weight array to achieve the domain target defined by the target DD parameters.

Systems and methods of surface steering control of drilling may be used together with systems and methods for planning one or more wells before drilling, planning a well path during drilling and/or updating that well plan and/or other well plans during the drilling of a well. The methods and systems may include planning a field, comprising a plurality of wells to be drilled and/or a plurality of pads from which a plurality of wells are to be drilled, planning a pad from which a plurality of wells are to be drilled, and planning a well both before and during drilling of the well.