A three-dimensional simulating device for the stratum stability in natural gas hydrate exploitation includes a three-dimensional model located in an environmental control unit, an axial pressure control unit, and a post-processing unit. An inner cavity of the three-dimensional model is divided into a sealed simulating cavity and a sealed axial pressure sealing cavity by an axial pressure sealing piston arranged in the inner cavity. A vertical well and a horizontal well stretch into the simulating cavity. The axial pressure control unit, the environmental control unit, and a plurality of sensors in the three-dimensional model are electrically connected to the post-processing unit. This simulating device simulates the external environment and combines in-situ synthesis and decomposition of a hydrate with stratum stability, thereby achieving high reliability and high accuracy, comprehensively evaluating mechanical characteristic change of the stratum and the stratum stability to provide guidance in natural gas hydrate exploitation.

A three-dimensional simulating device for the stratum stability in natural gas hydrate exploitation includes a three-dimensional model located in an environmental control unit, an axial pressure control unit, and a post-processing unit. An inner cavity of the three-dimensional model is divided into a sealed simulating cavity and a sealed axial pressure sealing cavity by an axial pressure sealing piston arranged in the inner cavity. A vertical well and a horizontal well stretch into the simulating cavity. The axial pressure control unit, the environmental control unit, and a plurality of sensors in the three-dimensional model are electrically connected to the post-processing unit. This simulating device simulates the external environment and combines in-situ synthesis and decomposition of a hydrate with stratum stability, thereby achieving high reliability and high accuracy, comprehensively evaluating mechanical characteristic change of the stratum and the stratum stability to provide guidance in natural gas hydrate exploitation.

Controlled fracturing in geologic formations is carried out by a system for generating fractures. The system comprises: a plurality of electrodes for placing in boreholes in a formation with one electrode per borehole, for the plurality of electrodes to define a fracture pattern for the geologic formation; a first electrical system for delivering a sufficient amount of energy to the electrodes to generate a conductive channel between the pair of electrodes with the conductivity in the channel has a ratio of final to initial channel conductivity of 10:1 to 50,000:1, wherein the sufficient amount of energy is selected from electromagnetic conduction, radiant energy and combinations thereof; and a second electrical system for generating electrical impulses with a voltage output ranging from 100-2000 kV, with the pulses having a rise time ranging from 0.05-500 microseconds and a half-value time of 50-5000 microseconds.

Methods of exploiting a formation containing a reservoir of hydrocarbons utilize a gas-liquid drift-flux (DF) model for a multi-segmented wellbore (MSW). The DF model is provided for use in conjunction with a reservoir simulator. The DF model is configured to account for pipe inclinations of the MSW between −90° and +90° including horizontal or near-horizontal wellbores in addition to vertical and slanted wellbores. The DF model is based on mixture velocity as opposed to superficial velocities, thereby permitting the DF model to be integrated with reservoir models that utilize mixture velocity. The DF model can also be continuous and differentiable over all primary variables.

Systems and methods for multiscale sectors based hydrocarbon reservoir simulation that include dividing a full-field reservoir model into regions and sub-regions, and iteratively assessing and reconnecting models of the sub-regions and regions in a sequential manner to generate an adjusted full-field model.

Systems and methods for multiscale sectors based hydrocarbon reservoir simulation that include dividing a full-field reservoir model into regions and sub-regions, and iteratively assessing and reconnecting models of the sub-regions and regions in a sequential manner to generate an adjusted full-field model.

A downhole installation comprises: a first pipe layer 8, a second pipe layer 10 about the first pipe layer 8, an annulus 12 between the first pipe layer 8 and the second pipe layer, and a geological formation outside of the second pipe layer 10. A method for evaluating the downhole installation comprises: exciting a flexural wave in the first pipe layer 8 using an angled acoustic transmitter 20; receiving third interface echo data using a plurality of angled acoustic receivers 14, 16 at different locations along the longitudinal extent of the pipe layers 8, 10; generating acoustic resonance across the thickness of the first pipe layer 8 and the second pipe layer 10 by use of full waveform excitation; receiving the acoustic response wave field generated by the full waveform; identifying a suitable component of the acoustic response wave field as being representative of the material state behind the second pipe layer 10; determining, based on the amplitude of the identified component and a suitable threshold value, if the material outside the second pipe layer 12 is fluid or solid; and analysing the third interface echo data in light of the determined material state in order to thereby evaluate material conditions in the annulus 12 outside the second pipe layer 10.

Provided are embodiments for hydrocarbon reservoir development that include the following: identifying proposed well locations within a reservoir boundary, for each location, developing a well plan by: (a) identifying layers of the reservoir located below the proposed location; (b) iteratively assessing the layers (from deepest to shallowest) to identify a deepest “suitable” layer that is not dry, congested, or unsuitable for gas production; and (c) performing the following for the identified layer and the location: (i) determining a borehole configuration for the location; (ii) determining a completion type for the location; and (iii) determining a stimulation treatment for the location, where a well plan for the location (e.g., for use in developing the reservoir) is generated that specifies some or all of a well location, the target layer, a borehole configuration, a completion type, and a stimulation treatment that corresponds to those determined for the proposed well location.

An intake manifold is provided having a base plate with discharge ports and an elongate pipe section extending along a face of the base plate. The pipe section has a front end with an intake port and progressively narrows at least adjacent a rear end. A first port in the rear end enables back-flushing of the manifold, and a second port in the rear end is angled relative to the base plate and enables insertion of a probe. Fork-lift openings extend between the base plate and the pipe section enabling the manifold to be lifted and positioned with a lift truck. Side ports extend through the pipe section and are angled relative to the base plate and adjacent one of the discharge ports to enable visual inspection of the discharge port. The side ports may include side ports located on both sides of the pipe section.

A hydrocarbon extractor (HE) evaluator system includes a central controller and an HE evaluator model that includes a hierarchical equipment model of heterogeneous HE type, subtype, and property, a plurality of rules arrangeable as a hierarchical equipment rule set, and as a hierarchical well feature rule set, a rules engine, the hierarchical well feature rule set formatted for a multi-factor comparison by the rules engine between heterogeneous HE types from disparate sources applied to the hierarchical equipment model. The rules engine configured to apply rules using class structure and one or more categories to an extracted portion of the hierarchical equipment model to generate results displayable to a user for determination of an HE type suitable for a particular well. A method for evaluating HE types and a non-transitory computer-readable medium containing instructions for a processor to perform the method are also disclosed.