227 results about "Formation fluid" patented technology

A system may include an orienting liner hanger disposed in a main bore of a multilateral well in a position downhole from a junction of the multilateral well. The system may also include a lower completion secured to a downhole end of the orienting liner hanger and a fluid separator assembly disposed uphole from the orienting liner hanger. The fluid separator assembly may be configured to receive formation fluid, which may include oil and water, flowing uphole from the lower completion. The fluid separator assembly may be configured to at least partially separate the formation fluid into formation oil and formation water. The fluid separator assembly may be configured to output formation oil to an upper production tubing and output the formation water into a lateral bore of the multilateral well.

A multilateral well system comprises a fluid separator to be positioned at a junction between a main bore and a lateral well of a multilateral well, wherein the fluid separator is configured to receive a formation fluid and to separate the formation fluid into production fluid and nonproduction fluid. The multilateral well system includes a pump to be positioned at the junction and configured to pump the nonproduction fluid to the lateral well for injection of the nonproduction fluid into a subsurface formation surrounding the at least one lateral well. The multilateral well system includes a first flow channel configured to be a conduit for delivery of the production fluid to the surface of the multilateral well and a second flow channel configured to deliver an injection of a surface fluid from the surface of the multilateral well into an injection zone downhole in the multilateral well.

A system may include a lower completion disposed in a main bore of a multilateral well in a position downhole from a junction of the multilateral well. The system may also include a fluid separator configured to receive formation fluid, which includes oil and water, flowing from the lower completion. The fluid separator may be configured to at least partially separate the formation fluid into formation oil and formation water. The fluid separator may also be configured to output the formation oil, via a separator oil outlet, to flow uphole, and output the formation water, via a separator water outlet, to flow toward a lateral bore of the multilateral well. Further, the system may include a water cut sensor disposed uphole from the fluid separator. The water cut sensor may be configured to measure the percentage of water in the formation oil.

The invention relates to the technical field of natural gas well exploitation, in particular to a water drainage, sand pumping and plug removal device for a power-free gas production pipe column and a using method. According to the technical scheme, the water inlet end of the lower portion of a nozzle is connected with a power water inlet formed in the outer wall of a pump body, a center pipe is arranged at the lower end of the nozzle, the water outlet end of the upper portion of the nozzle is communicated with a formation liquid inlet cavity, an expansion rubber barrel is arranged on the lower side of the pump body, and an upper pressure transmission hole is formed between the expansion rubber barrel and the center pipe; a slip rubber sleeve is arranged on the lower side of the pump body, a slip piece is arranged on the outer side of the slip rubber sleeve, a lower pressure transmission hole is formed between the slip rubber sleeve and the central pipe, and a formation liquid suction inlet is formed in the lower end of the pump body. A washing pipe is arranged at the bottom of the central pipe, and a sand suspending nozzle is arranged at the bottom of the washing pipe. The device has the beneficial effects that under the condition that a gas production pipe column is not moved, a continuous oil pipe is put into an inner cavity of the gas production pipe column to drive the device to pump sand, the sand pumping and plug removal requirements special for a natural gas well are met, and the well control safety and environmental protection problems of the natural gas well are avoided.

The invention relates to a preparation method of a carbon quantum dot tracing oil displacement mixture, the carbon quantum dot tracing oil displacement mixture is prepared by using a self-made carbon quantum dot tracer, a hydrophobic surfactant and a skeleton monomer as synthetic raw materials through a hydrothermal method, the agent contains hydrophobic groups, interfacial tension between water and oil can be reduced, and the oil displacement efficiency is improved. Dispersion and migration of oil drops in water are promoted, so that fluid flow becomes easy; meanwhile, the agent further comprises carbon quantum dots which can indicate the flowing path of formation fluid and evaluate the oil displacement effect of the synthetic agent and the microfracture distribution condition of a target formation, relates to the technical field of quantum dot tracing and oil displacement, and provides a new thought, method and technology for improving the recovery efficiency by adopting the agent on an oil field site.

The invention provides a device and method for measuring fractured gas reservoir-shaft coupling seepage key parameters, the device comprises a simulated stratum structure, a gas injection system, a drilling fluid injection system, a first outflow system and a second outflow system, the simulated stratum structure is provided with an accommodating space, and a rock core is arranged in the accommodating space; the gas injection system is communicated with the accommodating space in an openable and closable manner, and the gas injection system is provided with a first pressure detection piece and a first flow detection piece; the drilling fluid injection system is communicated with the accommodating space in an openable and closable manner, and the drilling fluid injection system is provided with a second pressure detection piece and a second flow detection piece; the first outflow system and the second outflow system are communicated with the simulated stratum structure in an openable and closable mode, the first outflow system is provided with a third flow detection piece, and the second outflow system is provided with a fourth flow detection piece. The device solves the problems that in the prior art, the condition of flow coupling of a shaft and formation fluid is not comprehensively considered, so that the device performance is poor, and the experiment effect is poor.

A fluid separator system may include a separator housing, a turbine chamber formed within the separator housing, and a fluid inlet configured to receive formation fluid and direct the formation fluid into the turbine chamber. The formation fluid may include oil and water. The fluid separator system may also include a turbine disposed within the turbine chamber and configured to rotate to at least partially separate the formation fluid into formation oil and formation water. Additionally, the fluid separator system may include an oil outlet configured to receive the formation oil separated from the formation fluid and direct the formation oil toward an upper production tubing and a water outlet configured to receive the formation water separated from the formation fluid and direct the formation water out of the separator housing.

Disclosed herein are methods and systems for identifying target analytes such as H2S and CO2 during downhole fluid analysis. The systems may include a fluid sampling tool comprising at least one probe to fluidly connect the fluid sampling tool to a formation in a wellbore, at least one passageway that passes through the at least one probe and into the fluid sampling tool, a sensor section comprising a measurement region in fluid communication with the at least one passageway, and a thin film deposited on the measurement region, wherein the thin film changes at least one of its physical properties upon exposure to the target analyte found in the at least one passageway. The methods may include disposing the fluid sampling tool into a wellbore, drawing a formation fluid from a sampling zone, and passing the fluid sample over the thin film deposited on a measurement region.

The invention discloses an underground complex working condition simulation device and method, the device comprises a simulation shaft, a drilling fluid injection mechanism, a drilling fluid discharge mechanism, a formation fluid injection mechanism and a formation fluid discharge mechanism, the simulation shaft comprises a mounting plate, a first fixing seat, a second fixing seat, an outer sleeve, an inner drill rod, an extrusion mechanism and a rotating mechanism; the drilling fluid injection mechanism is used for injecting slurry into one end of the outer sleeve. The device has the advantages that gas or liquid is injected into at least one side inlet through the formation fluid injection mechanism, so that gas cut or well kick during actual well drilling is simulated, leakage during actual well drilling is simulated through the formation fluid discharge mechanism, actual underground complex working conditions can be simulated in a laboratory through the device, and the working efficiency is improved. The method can create necessary conditions for indoor research of a rock debris migration process, well leakage, overflow, simultaneous occurrence of well leakage and overflow, and a three-phase flow process, and can be used for guiding establishment of a flow model and drilling construction.

The invention discloses a high-temperature-resistant and high-pressure-resistant autonomous deep well pressure maintaining sampler, and belongs to the technical field of drilling engineering sampling. The sampler comprises an upper joint, a control outer pipe, an end cover, a valve body and a liquid storage chamber which are connected in sequence, an electromagnet is arranged on the outer side of the end cover; an electric control module is arranged in the control outer pipe; a valve element with a permanent magnet is arranged in the valve body in a sliding mode, the valve element is driven to move axially through non-contact electromagnetic force between the electromagnet and the permanent magnet, and opening and closing of the sampling flow channel are achieved. The bottom of the valve core is provided with a valve core inner channel communicated with the sampling flow channel and the liquid storage chamber and a one-way valve; a sampling inlet channel is formed in the joint of the end cover and the valve body. According to the invention, a pure mechanical sealing-based structure is adopted, so that the sealing reliability and the operation stability in a high-temperature and high-pressure environment of a deep well are remarkably improved, drilling fluid is not needed, and efficient and pressure-maintaining sampling of in-situ formation fluid is realized.

The invention discloses an oil exploitation packer with an expanding type sealing structure, which belongs to the field of oil field downhole tools and comprises a central tube, an upper joint and a lower joint are respectively arranged at two ends of the central tube, a sealing component and a setting component are sequentially sleeved between the upper joint and the lower joint, and the upper joint and the lower joint are connected with a centralizing component and a reversing component in a matched manner. The sealing assembly comprises an installation pipe sleeved on the central pipe and a rubber sleeve sleeved on the outer side of the installation pipe, a first sliding rod and a second sliding rod which are alternately distributed and linked are arranged on the installation pipe in a sliding mode, and a first pushing block and a second pushing block are respectively hinged on the two sliding rods. When the two sliding rods move towards the setting assembly, the first pushing block and the second pushing block alternately penetrate and are spliced into a sealing ring with the outer diameter larger than the inner diameter of the rubber sleeve. The installation pipe provides a stable installation foundation for all the components, sliding rod linkage ensures that the pushing blocks move coordinately and synchronously, the sealing ring extrudes the rubber barrel to enable the rubber barrel to be expanded to be attached to the well wall to achieve sealing, and formation fluid channeling is effectively prevented. And by adjusting the radian of the push block and the length of the push rod, rapid sealing can be achieved under short-distance movement, and sealing reliability and response efficiency are improved.

The invention discloses a method and a system for predicting the vertical connectivity of a fault in a petroliferous basin, and relates to the technical field of fault connectivity detection.The method comprises the steps of determining a fault vertical connectivity coefficient of a target position according to influence factors of the fault vertical connectivity of the target position; the influence factors comprise the thickness of the fractured cover layer, the shale content, the normal stress of the fault surface, the formation fluid pressure, the brittleness degree of the cover layer and the fault displacement of the fault; the target position is the target position of a non-drilling area in the petroliferous basin; and predicting the vertical connectivity of the target position according to the fault vertical connectivity coefficient of the target position. According to the method, the identification accuracy of the vertical connectivity of the fault in the petroliferous basin is improved.

A system may include a lower completion disposed in a main bore of a multilateral well in a position downhole from a junction of the multilateral well. The system may also include a fluid separator configured to receive formation fluid, which includes oil and water, flowing from the lower completion. The fluid separator may be configured to at least partially separate the formation fluid into formation oil and formation water. The fluid separator may also be configured to output the formation oil, via a separator oil outlet, to flow uphole, and output the formation water, via a separator water outlet, to flow toward a lateral bore of the multilateral well. Further, the system may include a water cut sensor disposed uphole from the fluid separator. The water cut sensor may be configured to measure the percentage of water in the formation oil.

Methods and systems are disclosed herein. A method may include obtaining a well log of a well and obtaining a first fluid sample at a first one of the plurality of depths within the well. The method may include obtaining a second fluid sample at a second one of the plurality of depths within the well. The method may include determining a first fluid property from the first fluid sample and a second fluid property from the second fluid sample. The method may include determining a transform based on the first fluid property, the second fluid property, and the well log data. The method may include applying the transform to the well log data at a third one of the plurality of depths within the well yielding a first predicted fluid property. The method may include determining a subsurface development plan based on the first predicted fluid property.

Disclosed herein are systems and methods to obtain representative formation pore pressure and formation mobility from pressure measurements with a formation testing tool. In some embodiments, the method includes performing a first pre-test in which a pressure sensor measures a drawdown pressure and a buildup pressure, calculating a statistical value for the measured buildup pressure, determining if the statistical value is above or below a threshold, shutting down a mud pulser if the statistical value is above or below the threshold, and performing a second pre-test in which the pressure sensor measures a second drawdown pressure and a second buildup pressure. In embodiments, the second pre-test includes a formation fluid drawdown flow rate that is different than a formation fluid drawdown flow rate in the first pre-test.

The invention relates to the technical field of interpretation chart establishing methods, in particular to a formation fluid property evaluation chart establishing method based on nuclear magnetic resonance, which comprises the following steps of: analyzing three states of direct rock sample, soaking in water and soaking in manganese through nuclear magnetism, calculating correlation by utilizing analysis data, and establishing a formation fluid property evaluation method and chart. An oil layer area, an oil-water mixed layer area and a water layer area are effectively distinguished, the reservoir can be finely evaluated, and the oil-gas comprehensive interpretation coincidence rate is increased.

The invention belongs to the field of oil production engineering, and discloses a method for analyzing the sand-carrying capacity of a chemical flooding oil well, which comprises the following steps of: on the basis of calculating the viscosity of formation fluid in different stages of a polymer flooding production well, establishing a sand production quantity model of an oil well for producing liquid with the viscosity and a critical sand-carrying particle size model under the output liquid quantity; and judging whether the oil well has sand-carrying capacity or not through sand particle size analysis, sand content calculation and sand burying time of the pump cylinder. The method has high field applicability, can predict whether the chemical flooding production well can carry sand to produce oil or not in advance in the oil reservoir deployment stage, clearly determines which sand prevention and sand carrying lifting process mode is adopted, provides theoretical guidance for oil production engineering block scheme design, and improves the oil production efficiency. And meanwhile, technical support is provided for adjustment of a single-well sand prevention and sand carrying lifting process in different production and polymer concentration stages of the converted chemical flooding production well.

Techniques for controlling an amount of an acid gas in a production fluid includes operating a completion assembly that includes a production tubular, a first zone completion assembly, and a second zone completion assembly. The techniques include circulating a first formation fluid into the production tubular with a first flow control valve; circulating a second formation fluid into the production tubular with a second flow control valve; determining an amount or percentage of an acid gas in a production fluid that includes a mixture of the first and second formation fluids; comparing the determined amount of percentage to a threshold value; and modulating at least one of the first or second flow control valves in response to the comparison so that the production fluid meets the threshold value of the amount or percentage of the acid gas.

The invention provides a marine drilling shallow gas monitoring and shunting device and method. The marine drilling shallow gas monitoring and shunting device comprises a wellhead sealing and shunting device, a formation fluid monitoring and shunting device and a remote control device. The method comprises the steps of determining the direction of a blowout prevention pipeline, selecting the size of a blowout pipeline suitable for construction, establishing a calculation model and conducting risk assessment, conducting software comprehensive analysis to achieve early warning on early discovery of shallow gas, designing a pipeline anti-blocking purging device, and remotely controlling the blowout direction of the blowout pipeline. Through the novel wellhead sealing and shunting device, the micro-flow shallow gas monitoring device, the remote rapid shunting blowout device and the pipeline anti-blocking device, and a remote monitoring and control module, rapid judgment and early warning of early discovery of shallow gas are realized in a real-time sealed wellhead environment, and related valve states are rapidly acted, so that the safety of a well is ensured. And the well control risk is reduced, and the harm of shallow gas to a drilling platform and operators can be fundamentally solved.

A downhole fluid sampling system with hydraulic actuation can be used to collect one or more samples of formation fluid during a well operation. The sampling system can be within a downhole tool deployed in a wellbore of the well operation. Then sampling system then can collect a first sample from the flow of formation fluid from the wellbore using a first sampling chamber of a sampling unit in the sampling system. The sampling unit can define a set of sampling chambers including the first sampling chamber and a second sampling chamber. A piston of the sampling system that actuates on hydraulic fluid can advance the sampling unit by a predefined distance from a first position associated with the first sampling chamber to a second position associated with the second sampling chamber. Subsequently, the second sampling chamber can collect a second sample from the flow of formation fluid.

Processes for determining formation salinity and / or processes for identifying oil bearing and / or water bearing zones in freshwater or relatively low salinity formations. In some embodiments, the process for determining formation water salinity can include measuring resistivity of a formation fluid sample at a first temperature (T1) and at a second temperature (T2), where T1 and T2 can be separated by a temperature difference (ΔT). The process can also include calculating a resistivity factor value based on the resistivities measured at T1 and T2. The process can also include determining a salinity of the formation fluid sample based on the resistivity factor value and the ΔT. The process can also include initiating a downhole operation using the determined salinity of the formation fluid sample.

Techniques for controlling an amount of an acid gas in a production fluid includes operating a completion assembly that includes a production tubular, a first zone completion assembly, and a second zone completion assembly. The techniques include circulating a first formation fluid into the production tubular with a first flow control valve; circulating a second formation fluid into the production tubular with a second flow control valve; determining an amount or percentage of an acid gas in a production fluid that includes a mixture of the first and second formation fluids; comparing the determined amount of percentage to a threshold value; and modulating at least one of the first or second flow control valves in response to the comparison so that the production fluid meets the threshold value of the amount or percentage of the acid gas.

The present application relates to a kind of high temperature high pressure formation fluid containing large hole fracture plugging simulation device, including nitrogen bottle, liquid storage tank, simulation wellbore, heating insulation cover, back pressure valve and hole fracture isolation plate, there is inner cylinder in upper kettle body, there is simulation leakage layer in inner cylinder, upper kettle body and lower kettle body are connected by flange, hole fracture isolation plate is set between upper kettle body and lower kettle body, back pressure valve is set at the place close to hole fracture isolation plate of lower kettle body, heating insulation cover is set on the outer wall of upper kettle body and lower kettle body.The simulation method for high temperature high pressure formation fluid containing large hole fracture plugging using the above device, including: plugging slurry is discharged or passed through formation fluid and then enters simulation leakage layer;The plugging effect of conventional drilling fluid on small hole fracture leakage layer is judged by the pressure difference of upper kettle body and lower kettle body;The breakthrough pressure of sealing zone is obtained by the pressure difference between upper kettle body and lower kettle body after sealing zone is formed by solidified cementation type plugging slurry.The present application is in line with actual downhole, easy and fast to operate, provides platform and means for the plugging research of formation fluid containing large hole fracture leakage layer.

The invention discloses a natural gas hydrate reservoir in-situ fluid sampling device and method, and relates to the technical field of natural gas exploitation. The pumping module is used as a driving device for pumping formation fluid; the double-packer module comprises an upper packer and a lower packer, a sealed test interval is formed between the upper packer and the lower packer, and a pipeline connected with the pumping module penetrates through the upper packer to reach the test interval and is connected with a probe; the probe is used for penetrating out of a test interval to extract formation fluid; a lower packer, an upper packer and a pumping module are sequentially arranged from bottom to top from the bottom of the well; the in-situ fluid identification and sampling module comprises a PVT sampling barrel and a resistivity sensor; and the PVT sampling barrel and the resistivity sensor are connected to the pipeline between the upper packer and the pumping module and penetrate through the wall of the pipeline so as to measure the formation fluid extracted from the pipeline. The in-situ fluid under the original condition can be collected.

The invention relates to the technical field of material permeability experiment devices, in particular to a microscopic seepage model simulation device which comprises a clamping assembly, a box body with an upward opening and an upper gland with a transparent observation window in the middle. The device is reasonable and compact in structure and convenient to use, sandstone particles can be compressed in the simulation bin through the upper gland, and a simulated sandstone layer with the same structure as an oil reservoir stratum sandstone is formed; the seepage liquid can more uniformly enter the vertical micropores in the rectification strip through the left diversion trench, and the horizontal micropores communicated with the vertical micropores can enable the seepage liquid to uniformly flow into the simulation bin from the right side surface of the rectification strip in a layered manner, so that the seepage liquid can flow in parallel in the simulative sandstone layer; therefore, the seepage liquid can simulate one-dimensional linear flow in the simulated sandstone layer, the situation that the seepage liquid has excessive turbulent flow to influence an experiment result is avoided, the flowing state of deep stratum fluid laminar flow can be simulated more truly, and a better experiment result is obtained.

The application discloses a formation fluid identification method, comprising the following steps: acquiring first infrared spectrum data and second infrared spectrum data of a formation section to be interpreted; performing curve fitting on the first infrared spectrum data to obtain a fitting curve, determining a first factor according to an extreme value of a first wavelength section of the fitting curve, determining a second factor according to an opening and area integral of the fitting curve, and determining a third factor according to a center of a second wavelength section of the fitting curve; calculating a standard deviation curve of a standard deviation of longitudinal absorption at all wavelengths of a same depth point according to the second infrared spectrum data, and calculating a peak tailing factor of the standard deviation curve; and determining a type of the formation section according to the first factor, the second factor, the third factor and the peak tailing factor. The application further discloses a system, a computer device and a readable storage medium.

The invention discloses an experimental method and device for testing flowback performance of a proppant, and belongs to the technical field of hydraulic fracturing in oil exploitation, the method comprises the following steps: step 1, stirring prepared slurry by a stirring tank, and pressurizing and injecting the slurry into a simulated formation fracture flat plate model by a liquid injection pump; 2, when the fracturing fluid containing the propping agent is discharged at the constant flow speed, fracturing is completed; step 3, closing an emptying valve on a fracturing fluid output pipeline, closing a sealing plate by a simulated fracture closing module under the action of a gas source, applying closing pressure to simulate fracture closing, inputting liquid into a stratum at a certain pressure after the input gas source passes through a gas path containing an intermediate container, and simulating formation fluid production; and step 4, after the input gas source passes through the gas path only containing the pressure regulating valve, inputting gas into the stratum at a certain pressure, and simulating gas production of the stratum. The invention further discloses an experimental device for testing the flowback performance of the proppant. The invention studies the flowback conditions of the proppant under different conditions, and provides reference for reasonable preparation of the proppant.

The invention relates to the technical field of oil and gas well exploitation, in particular to a deep horizontal well segmented standard production and acidification combined operation device and a using method. According to the technical scheme, a vertical well section sampling testing device is connected into a shaft through an oil pipe, a horizontal section sampling testing and acidification device is connected to the lower portion of the shaft through a small-diameter oil pipe, an inner pipe is arranged at one end of an inner cavity of the horizontal section sampling testing and acidification device, an outer pipe is arranged on the outer side of the inner cavity of the horizontal section sampling testing and acidification device, and an upper expansion rubber sleeve is arranged on the outer side of the outer pipe; a formation liquid inlet is located between the two, a storage type tester is arranged in an inner cavity at the tail end, and dynamic production data are tested through the storage type tester; and during acidification, acidizing fluid is reversely injected into the stratum between the upper expansion rubber sleeve and the lower expansion rubber sleeve along the stratum fluid inlet. The method has the beneficial effects that the data of the produced liquid of each well section can be conveniently measured in real time, and the spot test data is reliable; in addition, acidification production increase can be carried out on all well sections, and multiple purposes are achieved through one pipe column.

The invention belongs to the field of oil field shale gas exploration and development experiments, and particularly relates to a shale gas volume testing method. According to the invention, after the shale sample is placed in the set test environment, the basic stratum condition corresponding to the shale sample is constructed, and the drilling coring cooling and depressurization process is simulated according to the actual condition of related parameters in the process of pulling out the drill core to test the gas loss; therefore, the testing environment of the lost gas volume is more fit with the actual condition during drilling and coring, large errors generated by theoretical analysis can be avoided, and the accuracy of the testing result of the lost gas volume is effectively improved; the shale sample is recovered to the temperature and pressure conditions of the reservoir by simulating the formation fluid and adjusting the temperature and the pressure, so that the shale is fully saturated and adsorbs the simulated formation fluid, and therefore, the basic formation condition corresponding to the shale sample, which is more fit with the actual formation condition, is constructed and is used for testing the gas volume of the shale; and the accuracy of shale gas volume testing is ensured.

The present application belongs to the field of oilfield shale gas exploration and development experiment, and particularly relates to a shale gas quantity testing method. The present application constructs the basic formation condition corresponding to the shale sample by placing the shale sample into a set testing environment, and tests the lost gas quantity by simulating the drilling core lowering temperature and pressure process according to the actual situation of the related parameters in the process of drilling core taking, so that the testing environment of the lost gas quantity is more consistent with the actual situation when drilling core is taken, thus the large error generated by theoretical analysis can be avoided, and the accuracy of the testing result of the lost gas quantity is effectively improved. Furthermore, the shale sample is restored to the temperature and pressure conditions of the reservoir by adjusting the formation fluid, temperature and pressure, so that the shale is fully saturated and adsorbs the simulated formation fluid, thereby the basic formation condition corresponding to the shale sample which is more consistent with the actual formation condition is constructed, and is used for testing the shale gas quantity, so as to ensure the accuracy of the shale gas quantity testing.