178 results about "Field development" patented technology

This invention relates to the field of oil and gas field development, and discloses a full-scale DAS (Digital Angiography and Semiconductor) device and method for monitoring the integrity of hydrate development wellbore. The device includes a formation simulation device, a wellbore simulation device, and a monitoring device. The formation simulation device comprises a temperature control system, a pressure control system, and a simulated formation. The temperature control system, pressure control system, and simulated formation are connected to the wellbore simulation device. The temperature control system and pressure control system are used to simulate the actual temperature and pressure of the hydrate formation. The simulated formation is prepared according to the actual mineral composition and grain size distribution of the hydrate reservoir. The monitoring device is located outside the wellbore simulation device and works in conjunction with the formation simulation device to perform real-time, full-well-section monitoring during hydrate development. This invention can simulate real wellbore conditions and perform real-time, continuous monitoring of the entire wellbore to meet the needs of dynamic downhole monitoring in actual production.

This invention belongs to the technical field of oil and gas field development and enhanced oil recovery, specifically relating to a bio-based ternary composite enhanced oil recovery system and its preparation method. The bio-based ternary composite enhanced oil recovery system of this invention, by weight, comprises: 800-2000 parts of biopolymer; 600-3000 parts of biosurfactant; 40-400 parts of bionanomaterials; and 200-800 parts of water. In the bio-based ternary composite enhanced oil recovery system provided by this invention, the composite enhanced oil recovery system of biopolymer, biosurfactant, and bionanomaterials fully leverages the synergistic effect of each component, demonstrating significant advantages in improving crude oil recovery and reducing environmental risks, and possessing good industrial application prospects and promotional value.

A core permeability testing device and method are disclosed, belonging to the technical field of oil and gas field development. The testing device includes a core holder for holding the core to be tested; a constant temperature chamber for providing the testing environment temperature, which is equal to the temperature of the tight gas reservoir; the core holder and the core to be tested are placed inside the constant temperature chamber; a confining pressure loading pump for applying confining pressure to the core holder, the magnitude of which is equal to the pressure of the overlying strata of the tight gas reservoir; and a high-pressure gas cylinder for pressurizing a standard container, which is connected to the core holder. The standard container forms upstream and downstream pressures applied to the core holder according to the formation pressure of the tight gas reservoir. The core permeability under temperature, pressure, and saturation conditions is obtained by measuring and calculating. The testing device of this invention has a simple structure, and only pressure needs to be measured during the testing process, without the need to measure flow rate, which can effectively improve the evaluation effect of tight gas reservoir permeability.

This invention relates to a star-rating management method and system for the deployment and implementation of gas field development wells, belonging to the field of gas field development technology. The invention first establishes an initial production estimation expression and dimensionless production curves for gas wells using dynamic production data from existing similar gas wells. Then, it uses these results to determine the production rate of newly deployed gas wells and, based on production and cost, determines the internal rate of return (IRR) for these wells. If the required IRR is not met, the deployment location and construction process of the new wells are re-optimized until the required IRR is achieved. Simultaneously, the star rating of the gas well's economic benefit is determined based on the IRR. Drilling is then carried out at the new well deployment location that meets the economic development requirements. After drilling, a more detailed fracturing design is conducted, and the IRR and star rating of the gas well are re-determined according to the new design. This invention effectively improves the targeting of single-well geological design and fracturing construction design, thereby improving development results and quality.

The present application relates to oil and gas field development technology, disclose a kind of heavy oil reservoir hot water drive limit well spacing determination method. Including the following steps: S1, the starting pressure gradient corresponding to different temperature is obtained by percolation experiment test;S2, according to the starting pressure gradient corresponding to different temperature, determine the inflection point temperature of starting pressure gradient curve;S3, based on the inflection point temperature of pressure gradient curve, the percolation area between injection well and production well is divided;S4, based on the percolation area divided, the percolation resistance R of darcy percolation area between injection well and production well is calculated d ;S5, based on R d The pressure drop ΔP of darcy percolation area between injection well and production well is calculated d ;S6, based on ΔP d The length l of non-darcy percolation area between injection well and production well is calculated nd ;S7, based on l nd Determine the limit well spacing L of heavy oil reservoir hot water drive. The determination method can guide the formulation of heavy oil reservoir hot water drive development plan, improve development effect.

The invention discloses a preparation method and application of sand control fluid in an outer annular space of an oil-string casing, and belongs to the technical field of oil-gas field development. The preparation method comprises the steps that S1, the perforation aperture of the oil-string casing and the sand grain size and temperature of a sand production oil layer are obtained; s2, uniformly mixing a non-metallic mineral material, pulverized coal and natural organic compound particles, adding water, and roasting to prepare porous microspheres; s3, paraffin is added, and microspheres wrapping the paraffin are prepared; and S4, adding water and cement to prepare a primary sand control fluid, and adding a retarder or an accelerator to enable the primary sand control fluid to meet the set initial setting time to prepare the sand control fluid. After the prepared sand prevention fluid is solidified, the paraffin can be melted and discharged at the oil layer temperature, so that a sand prevention barrier is formed in an annular space outside an oil-string casing, and due to the fact that the microspheres are porous, a wellbore in the casing is communicated with a sand outlet oil layer, oil gas can enter an oil pipe through pores to be normally exploited and produced, and sand grains are isolated outside. The method is suitable for oil layer sand prevention in oil-gas field exploitation.

The present application relates to the technical field of oil and gas field development, in particular to a kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir.A kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir, the reserve control degree of gas reservoir=(the control reserves of all gas wells-intersection control reserves-waste control reserves) / geological reserves of gas reservoir.The present application establishes a kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir, considers the difference of different production layer control radius and control reserves, and has important guiding significance to the effective development of multi-layer superimposed gas reservoir.

The present application belongs to the technical field of oil and gas field development, and particularly relates to a method and device for characterizing the evolution of a seepage field in the whole development cycle of an oil reservoir, aiming to solve the problem that the seepage field cannot be simultaneously characterized in a single stage and development history control in the prior art. The method comprises: obtaining data in the whole development cycle of the oil reservoir as input data; based on the input data, checking a dynamic and static multi-information correlation model of the oil reservoir; combining the checked dynamic and static multi-information correlation model of the oil reservoir, calculating a pressure trend field, and then obtaining a velocity field; according to the velocity field, using a particle tracking calculation method, characterizing the seepage field through a streamline field, and generating the seepage field of the oil reservoir in different development stages; combining the seepage field of the oil reservoir in different development stages, constructing the evolution characterization of the seepage field in the whole development cycle and the evolution characterization feature index of the seepage field in the whole development cycle. The present application solves the problem that the seepage field cannot be simultaneously characterized in a single stage and development history control in the prior art.

This invention discloses an integrated intelligent device and control method for oil and gas negative pressure suction and booster mixed transportation, relating to the field of oil and gas field development booster technology. It includes a heating unit and a pumping unit connected sequentially from the direction of produced fluid transportation. The pumping unit includes two booster pump sets connected to the oil outlet pipeline of the heating unit. The two booster pump sets are connected in parallel and alternately suction and transport the produced fluid in the oil outlet pipeline. The heating unit's pretreatment method, which reduces the viscosity of the produced fluid and improves its fluidity, creates favorable conditions for subsequent pumping. The operation mode of two sets of booster pump sets connected in parallel and alternately suctioning can form a continuous and stable negative pressure in the oil outlet pipeline, effectively avoiding fatigue overload and airlock phenomena caused by continuous operation of a single pump set. This ensures that high-viscosity or gas-containing produced fluid can be smoothly and continuously sucked in and discharged, thereby significantly improving the operational reliability and pumping efficiency of the entire transportation system.

The application discloses a kind of multiphase state CO2 jet flow simulation experiment device and experimental method thereof, it is related to oil and gas field development, carbon dioxide geological storage (CCUS) technical field, experimental device includes: the pressure-bearing unit that can be opened, for storing dry ice, when pressure-bearing unit is closed, pressure-bearing unit is closed state;Pressure relief structure is installed on pressure-bearing unit, with pressure-bearing unit inside communication, and when the pressure of pressure-bearing unit inside reaches preset value, pressure relief structure makes that pressure-bearing unit inside and outside communication;Wellbore simulation unit, including casing, casing is transparent, pressure-bearing unit and pressure relief structure are arranged in casing;Heating assembly, for heating casing;Temperature measuring unit;Pressure measuring unit;High-speed camera device, etc..The present application can solve the problem that CO2 source uses high-pressure gas cylinder direct gas supply mode to simulate leakage process in existing experiment, which cannot simulate CO2 leakage caused by solid phase blockage, pressure accumulation in closed space and other factors in actual field.

This invention provides a method for predicting the pressure distribution of a shale gas horizontal well in a gas-liquid two-phase flow wellbore, belonging to the field of oil and gas field development. The method includes: dividing the target shale gas horizontal well into target well sections; performing a detailed simulation of the target well sections to obtain detailed simulation results; determining the functional relationship between the gas-liquid two-phase slip velocity and the average transport rate of the water phase in the target well based on the detailed simulation results of the target well sections; determining the functional relationship between the resistance coefficient and the outlet liquid holdup of the target well based on the detailed simulation results of each target well section; establishing a wellbore control coupling model for the target well based on conservation theorems, the functional relationship between the gas-liquid two-phase slip velocity and the average transport rate of the water phase, and the functional relationship between the resistance coefficient and the outlet liquid holdup; iteratively solving the wellbore control coupling model for the target well; and obtaining the pressure distribution of the shale gas horizontal well based on the iteration results to achieve accurate and efficient pressure distribution prediction.

This invention provides an experimental apparatus and method for simulating the phase state of fluids in oil and gas reservoirs, belonging to the field of experimental technology for fluid phase state in oil and gas field development. It includes: a support frame with a first cavity, a second cavity, and a third cavity arranged from top to bottom; a pressure regulating mechanism for adjusting pressure is installed in the second and third cavities; the first cavity is connected to the second cavity via a first pipe and a second pipe, and the first cavity is connected to the third cavity via a third pipe; the second cavity is connected to the third cavity via a fourth pipe; an output pipe is located at the top of the first cavity, with the inlet of the output pipe located inside the first cavity and lower than the opening of the first pipe on the first cavity; valves for controlling the opening and closing of the output pipe, the first pipe, the second pipe, the third pipe, and the fourth pipe are all installed. This invention has a simple structure, is easy to use, and can accurately simulate the depletion development process of oil-bottom-water type oil and gas reservoirs in upper gas formations, clearly defining the phase change characteristics of formation fluids.

This invention discloses a method and system for intelligently determining critical pressure based on multi-level matching data, comprising the following steps: data acquisition and preprocessing; executing a hierarchical matching strategy according to a preset priority order to select relevant overburden pressure porosity and permeability experimental data points for the target reservoir from a core physical experimental database; pressure-permeability curve fitting; critical pressure determination; and outputting the critical pressure value and related analysis results. This invention significantly improves the efficiency, accuracy, and automation level of critical pressure assessment based on overburden pressure porosity and permeability experimental data, reduces excessive reliance on new, high-cost, long-cycle overburden pressure experiments, and provides more reliable and timely technical support for refined pressure management, reservoir protection strategy formulation, production enhancement measure optimization, and core analysis experimental pressure threshold calculation during oil and gas field development.

This invention belongs to the technical field of experimental equipment for oil and gas field development engineering, specifically relating to a visualization device and method for simulating solid phase deposition in the flow of waxy crude oil in a wellbore. This invention connects two or more wellbore simulation units in series to form a wellbore flow simulation system. A coiled section and a sapphire glass visible section are connected in series and placed within a visible temperature control device, enabling the simulation of temperatures at different locations in the wellbore. Furthermore, the sapphire glass visible section can be removed entirely. This invention is simple to operate and can realistically simulate the solid phase deposition behavior of crude oil on the metal wellbore wall. It solves the problems of existing visualization devices being unable to handle high-pressure conditions and accurately reproduce the actual flow environment in the wellbore, and also better addresses the issue of existing devices being unable to achieve in-situ sampling while maintaining the integrity of the wax crystal microstructure.

This disclosure relates to the field of oil and gas field development technology, and discloses a method for sand control and cabled water injection completion. The method includes: determining a cabled intelligent water injection string based on the number of layers to be injected and the length of each layer in the target well; running the cabled intelligent water injection string into the target well that has undergone layered sand control treatment; and testing and adjusting the cabled intelligent water injection string. This method can simultaneously perform sand control and cabled water injection operations on the target layer, enabling precise water injection during daily production, real-time dynamic monitoring of the target layer, and dynamic adjustment as needed, thus improving the intelligence level of well completion.

This invention discloses a high-pressure foam forming device based on Tesla valves, including a generating chamber with a foam discharge hole at the upper end and a liquid injection valve and a gas injection valve at the lower end. The generating chamber contains several Tesla valves connected end-to-end. Each Tesla valve has a filter screen at both its upper and lower ends, and each Tesla valve is equipped with a liquid injection valve and a gas injection valve. The liquid injection valve and gas injection valve are intermittently connected to the main / branch flow channels of the Tesla valves. The invention also discloses a method for using the device. This invention is applicable to the field of oil and gas field development technology. Based on the foam working pressure requirements and referring to the indicator diagram, it can generate a relatively stable foam system under various pressure environments. The connection method is simple, the operation is convenient, and it comprehensively meets the experimental requirements under various pressures.

The application discloses an in-layer well arrangement method for deep shale gas and a related device, relates to the technical field of oil and gas field development, and comprises the following steps: performing geological sweet spot evaluation on reservoir geological parameters, performing engineering sweet spot evaluation on engineering parameters, obtaining the geological sweet spot evaluation result and the engineering sweet spot evaluation result, and determining a platinum target body of a target block; obtaining position parameters of a lower high-quality target layer section and an upper high-quality target layer section in the platinum target body; generating an in-layer initial well arrangement scheme based on the position parameters; inputting the in-layer initial well arrangement scheme into a hydraulic fracturing numerical simulation model; carrying out multiple-group hydraulic fracturing numerical simulation; obtaining crack shape data and post-production pressure evolution data corresponding to each group of simulation results; comparing and analyzing each group of simulation results according to the crack shape data and the post-production pressure evolution data; and outputting an optimal inter-well spacing and an optimal longitudinal target body combination. The application significantly reduces the risk of inter-well channeling, improves single-well productivity and the overall development efficiency of a platform.

The application belongs to the technical field of oil and gas field development, and discloses a method and device for measuring the thickness of a soft rock area after long-term fracture diversion, which comprises the following steps: obtaining a core sample to be measured; performing layer-by-layer scratch at equal depth on the fracture diversion surface of the core sample to be measured; collecting discrete horizontal displacement data in real time during the process of each layer of scratch, and determining the corresponding discrete fracture toughness value; for each layer of scratch, determining the curve of the change of fracture toughness with scratch displacement based on the discrete horizontal displacement data and the discrete fracture toughness value, and calculating the average fracture toughness of all discrete points within the range of each layer of scratch; calculating the difference between the average fracture toughness of two adjacent layers, and determining that the soft and hard rock interface has been reached when the difference between the average fracture toughness of two adjacent layers is not greater than a first preset threshold; and calculating the thickness of the soft rock area according to the total number of scratches and the single-layer scratch depth when the soft and hard rock interface is reached. The application can realize efficient and high-precision quantitative measurement of the thickness of the soft rock area.

This invention provides a hydraulic pressure-thermal bath coupled true triaxial loading and panoramic real-time CT scanning device, belonging to the fields of rock mechanics, oil and gas field development, and tight sandstone gas extraction. It overcomes the problem in existing rock mechanics experimental devices where true triaxial loading, hydraulic loading, thermal bath environment control, and internal structure observation are difficult to achieve in a single space. The device includes an X-ray scanning system, a forward and backward precession loading system, a temperature-controlled liquid circulation system, and a multi-functional pipeline system with signal linkage, forming a multi-field loading control system. This multi-field loading control system is configured to: monitor the rate of change of loading force, hydraulic pressure, and temperature in each loading direction in real time, and dynamically adjust the frequency or scanning mode of the CT scan based on the monitored parameter change rates.

This invention provides a repeated fracturing method using flexible knotted temporary plugging balls to seal perforations, belonging to the field of oil and gas field development. The method first identifies oil and gas enrichment zones and completes wellbore pretreatment. Then, slickwater is injected to divide the horizontal well section into three zones based on pressure drop and flow velocity. Gel fracturing fluid is injected into the high-filtration-velocity zone to seal old fractures. Subsequently, temporary plugging balls of different sizes are deployed according to the characteristics of each zone, with pressure-flow dual monitoring to address leakage and accumulation. Mixed sand hydraulic fracturing is injected and parameters are dynamically adjusted. Finally, the wellbore is cleaned and the effect is evaluated. This invention solves the problem of leakage and accumulation of temporary plugging balls due to uneven flow field in the horizontal section, reducing the leakage rate to below 8% and the accumulation rate to below 5%, with a target perforation reach rate exceeding 92%, significantly improving reservoir stimulation effectiveness and production capacity.

The application belongs to the technical field of oil and gas field development, and particularly relates to a porosity determination method, device, electronic equipment and storage medium. The porosity determination method comprises the following steps: obtaining seismic data and measured well data of a target area; establishing a geometric structure model of a fracture-vug type reservoir according to the seismic data; establishing a three-dimensional numerical well test model according to the geometric structure model and a corresponding fluid model; obtaining bottom hole pressure simulation data in the three-dimensional numerical well test model; and determining target porosity of the target area according to the bottom hole pressure simulation data and the measured well data. The application establishes a geometric structure model of a fracture-vug type reservoir through seismic data of a target area, then establishes a three-dimensional numerical well test model according to the geometric structure model, and finally determines target porosity of the target area by comparing bottom hole pressure simulation data of the three-dimensional numerical well test model with measured well data, thereby solving the problem of porosity assignment of a fracture-vug type reservoir.

The embodiment of the invention provides a method and equipment for numerical simulation of shale oil reservoirs among salts, and belongs to the technical field of oil-gas field development. The method comprises the following steps: acquiring geological engineering parameters of a target block; obtaining a core sample of a target reservoir of the target block, and measuring the solid mineral type and the soluble mineral type and content of the core sample; according to the geological engineering parameters of the target block, the solid mineral type and the soluble mineral type and content of the core sample, establishing a component numerical simulation model of the inter-salt shale oil reservoir to be simulated; obtaining an initial first characteristic parameter of each grid in the component numerical simulation model, and setting a time step; and executing component simulation based on the first characteristic parameter. According to the method, the accuracy of simulating the development process of the inter-salt shale oil is improved by considering the salt-soluble crystallization effect in the development process of the inter-salt shale oil reservoir and the pore permeability condition change caused by the salt-soluble crystallization effect.

This application provides a numerical simulation method, apparatus, and storage medium for asphaltene deposition unblocking, belonging to the field of oil and gas field development technology. The method includes: constructing a thermodynamic component model containing asphaltene based on reservoir fluid composition; calculating oil-solid phase equilibrium conditions using equations of state; setting a critical mole fraction for asphaltene precipitation in the oil phase, where precipitation occurs when the actual mole fraction is greater than or equal to the critical value; setting reaction paths for precipitation and unblocking reactions; establishing a porosity-permeability coupled evolution model, where porosity decreases linearly with solid deposition, and permeability decreases power-lawically with decreasing porosity; embedding the above model into a reservoir numerical simulator, and dynamically updating the asphaltene concentration, solid deposition, porosity, and permeability parameters of each grid through time-step numerical solutions.

This utility model discloses a novel anti-breakage and anti-sand gas well choke in the field of oil and gas field development equipment technology. It includes a release mechanism, a choke mechanism, an unsealing mechanism, a straightening mechanism, an anchoring mechanism, an anti-breakage mechanism, a sealing mechanism, a locking mechanism, an anti-sand mechanism, and a choke body. These mechanisms are sequentially connected to the choke body. The anti-breakage mechanism includes a one-way sliding lock sleeve, which cooperates with the anchoring and locking mechanisms. Through the combined action of the anchoring and locking mechanisms, along with a double-layer sealing and anti-sand design, this utility model ensures that the choke does not break off under downhole impact or vibration conditions, significantly reducing the risk of downhole debris, improving gas well safety, and reducing methanol dependence and wellhead equipment pressure risks.

The invention belongs to the technical field of gas field development, and discloses a production pipeline accumulated liquid purging method utilizing intermittent gas well group energy, which comprises the following steps: monitoring the state of a production pipe network, acquiring data of each pipe section of the production pipe network, determining the accumulated liquid position of the pipe network, diagnosing the accumulated liquid amount of the pipeline by utilizing analogue simulation, and establishing a pressure difference-conveying efficiency chart. The method comprises the steps of determining the optimal purging opportunity of a pipeline, simulating pipeline purging conditions of an intermittent well under different well opening and closing systems by utilizing a simulation model, determining the optimal well opening and closing system according to purging efficiency, and forming a field pipeline purging scheme according to the optimal purging opportunity and the optimal well opening and closing system. Implementing a purging scheme, and evaluating the purging effect according to the pipe network node pressure. According to the invention, reliable, simple and efficient accumulated liquid management of the natural gas gathering and transportation pipeline is realized, the dependence on physical depressurization emptying operation is reduced, natural gas resource waste and environmental pollution are obviously reduced, and the field operation and maintenance cost is reduced.

This invention relates to a method for determining the migration front and damage distance, and a fracturing simulation system, relating to the field of oil and gas field development. The method includes: controlling an injection device to sequentially perform carbon dioxide injection, fracturing fluid injection, and well shut-in operations on a core sample to simulate a carbon dioxide pre-fracturing process; at each stage of the simulation, controlling a monitoring device to acquire fluid migration data of the core sample; determining the location or migration distance of the carbon dioxide migration front within the core sample based on the fluid migration data; acquiring damage response data for multiple core segments within the reservoir section, the damage response data being used to characterize the cumulative damage degree of the core sample caused by the simulation process; determining damage boundary data of the core sample based on the damage response data; and determining damage hysteresis data, used to characterize the spatiotemporal coupling relationship between carbon dioxide migration and core damage, based on the migration front data and the damage boundary data.