The present disclosure belongs to the field of capture, utilization, and storage of carbon dioxide, particularly relates to a method and system for intelligently identifying a carbon storage box based on a GAN network, and aims at solving the problem that the analysis accuracy of a fault zone area in the prior art is insufficient. The method comprises the steps: delineating seismic waveform data of a stable sedimentary area through a GAN network, and removing seismic waveform data points in the fault zone area; obtaining a stable sedimentary background seismic waveform data invertomer; obtaining a three-dimensional wave impedance prediction data volume; making a difference to obtain an abnormal wave impedance data volume; retaining abnormal wave impedance data of fault-karst in the three-dimensional variance attribute volume to obtain a fault-karst wave impedance data volume; and then obtaining a carbon storage box interpretation model.

A threaded connection for large diameter steel pipe exhibits high torque resistance and high sealability and, at the same time, provides a shear resistance that suits the size of the steel pipe to be connected. The threaded connection includes a tubular pin provided on a tip of a steel pipe with large diameter, and a tubular box 20 adapted to be drawn up on the pin as the pin is screwed in. The pin includes a male threadform made with a taper thread. The box includes a female threadform made with a taper thread. Each of the threadforms are wedge threads and have a dovetail-shaped cross section. The male threadform is designed such that the width of the thread in an end region of the male threadform closer to the tip is set to a size corresponding to the size of the pipe body of the steel pipe.

The present invention relates to a reagent for exploiting natural gas hydrates, which includes a regent A and a regent B. The reagent A is PEG400-polyurethane prepolymer; the reagent B includes PEG400 and an initiator; and a volume ratio of the PEG400-polyurethane prepolymer, the PEG400 and the initiator is (1-3000):(1-1000):(1-2000). The reagent of the present invention has excellent performance and high stability, and can effectively “replace” the “water” of the natural gas hydrate; and moreover, the reaction is exothermic reaction to effectively increase the reaction rate, which reduces the energy loss on the one hand, and reduces the blockage of a gas passage caused by the secondary generation of the natural gas hydrates in a low-temperature high-pressure pipeline during transferring on the other hand.

A method for enhancing geological storage by injecting nanoparticles to stabilize CO.sub.2 microbubbles, which belongs to the technical field of multiphase flow. The method first improves the physical properties of the fluid by pre-mixing CO.sub.2 and nanoparticles, and then the fluid is transported to the underground through high-pressure pipelines, and then CO.sub.2 microbubbles containing nanoparticles are generated through a dense perforated plate arranged by an injection well to improve the dissolution rate and sweep efficiency of the gas in the saline aquifer, so as to enhance the later mixing of the fluid. The combined injection can improve CO.sub.2 storage capacity and storage safety, and further reduce the risk of gas leakage in the reservoir.

Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO.sub.2 flooding are disclosed. One method comprises producing a well stream from the reservoir; separating the well stream into a liquid phase and a gas phase with a first gas/liquid separator, wherein the gas phase comprises both CO.sub.2 gas and hydrocarbon gas; cooling the gas phase with a first cooler; compressing the gas phase using a first compressor into a compressed stream; mixing the compressed stream with an external source of CO.sub.2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO.sub.2 flooding are also disclosed.

The present invention generally relates to the composition of particle gels for CO.sub.2-EOR and CO.sub.2 storage. More particularly, CO.sub.2 resistant particle gels are provided that can re-crosslink at subterranean conditions. These particle gels can be deployed to improve the conformance of CO.sub.2 flooding, CO.sub.2 huff-puff, or Water-Alternative-Gas (WAG). The applications may also involve CO.sub.2 storage, such as the blocking of CO.sub.2 leakage and similar CO.sub.2 processing.

Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO.sub.2 flooding are disclosed. One method comprises producing a well stream from the reservoir; separating the well stream into a liquid phase and a gas phase with a first gas/liquid separator, wherein the gas phase comprises both CO.sub.2 gas and hydrocarbon gas; cooling the gas phase with a first cooler; compressing the gas phase using a first compressor into a compressed stream; mixing the compressed stream with an external source of CO.sub.2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO.sub.2 flooding are also disclosed.

A system comprises an injection well for accessing reservoir at a first temperature; a production well in fluid communication with the reservoir; a working-fluid supply system providing a non-water based working fluid to the injection well at a second temperature lower than the first temperature, wherein exposure of the working fluid to the first temperature heats the working fluid to a third temperature and at least a portion of the working fluid at the third temperature is produced as a production fluid; and an energy recovery system that converts energy contained in the production fluid to electricity or heat, wherein the energy recovery system includes a waste heat recovery apparatus that recovers waste heat and uses it to heat the production fluid to a fourth temperature that is higher than the third temperature, wherein the waste heat is recovered from equipment of or a process stream.

A crop prediction system performs various machine learning operations to predict crop production and to identify a set of farming operations that, if performed, optimize crop production. The crop prediction system uses crop prediction models trained using various machine learning operations based on geographic and agronomic information. Responsive to receiving a request from a grower, the crop prediction system can access information representation of a portion of land corresponding to the request, such as the location of the land and corresponding weather conditions and soil composition. The crop prediction system applies one or more crop prediction models to the access information to predict a crop production and identify an optimized set of farming operations for the grower to perform.

The invention is directed to methods for improving the recovery of oil from subterranean geological formations, such as unconventional reservoirs. The invention is also directed to methods for evaluating the efficiency of inject-soak-produce gas injection methods for oil recovery in unconventional reservoirs. In one embodiment, a method for evaluating the efficiency of oil recovery from an unconventional reservoir rock sample includes characterizing the rock sample by imaging the rock sample using a nano-CT scanner and/or scanning electron microscopy (SEM); cleaning the rock sample by flowing solvent through it; saturating the rock sample with crude oil; and establishing initial water saturation in the rock sample.