876 results about "Field development" patented technology

The invention provides a method for analyzing remaining oil distribution of a fractured-vuggy reservoir, belonging to the fields of numerical reservoir simulation and oil-gas field development. In the method, a complex medium consisting of a cave medium, a crack medium and a pore medium is partitioned into a plurality of space unit blocks in a space field; each block consists of V, F and M units which represent a cave, a crack and a substrate in the block respectively and constitute a V-F-M model; the flow of a multi-phase fluid in the complex medium is described by the motion of a fluid among the units in each block and the motion of a fluid among the units of different blocks; and the flow of the fluid among the units can be considered as infiltration flow, pipe flow or laminar flow between parallel walls, Darcy flow or non-Darcy flow. According to the method, scientific description and accurate numerical simulation of the fractured-vuggy reservoir are realized, and technical foundations are laid for the alignment of the remaining oil distribution position of the fractured-vuggy reservoir with a numerical simulation technology, quantitative determination of the reserves abundance of the reservoir, scientific and reasonable development of oil fields provided with the reservoir and final increase in the recovery ratio.

The invention discloses a method for predicting yield of a compact hypotonic gas field multistage fracturing horizontal well, and belongs to the field of gas field development. The new method for predicting the yield of the compact hypotonic gas field multistage fracturing horizontal well is provided for solving the problem that an existing horizontal well yield prediction model does not give consideration to influences of factors such as uneven stratums, an air layer drilling encountering rate, a percolating resistance gradient, a variable fracture interval and a variable pressure fracture scale on the fracturing horizontal well yield, can be used for the yield prediction of the compact hypotonic gas field multistage fracturing horizontal well, and provides bases for development, design and optimization. The example verification results show that the prediction results of the method are quite close to measured data of the multistage fracturing horizontal well, and the effect is good. The method for predicting the yield of the compact hypotonic gas field multistage fracturing horizontal well fills the blank that a fracturing horizontal well yield prediction model can simultaneously give the consideration to the influences of the factors such as the uneven stratums, the air layer drilling encountering rate, the percolating resistance gradient, the variable fracture interval and the variable pressure fracture scale on the fracturing horizontal well yield, has the advantages of being simple, strong in operability, effective, practical and the like, and therefore has good popularized use value.

A hybrid evolutionary algorithm (“HEA”) technique is described for automatically calculating well and drainage locations in a field. The technique includes planning a set of wells on a static reservoir model using an automated well planner tool that designs realistic wells that satisfy drilling and construction constraints. A subset of these locations is then selected based on dynamic flow simulation using a cost function that maximizes recovery or economic benefit. In particular, a large population of candidate targets, drain holes and trajectories is initially created using fast calculation analysis tools of cost and value, and as the workflow proceeds, the population size is reduced in each successive operation, thereby facilitating use of increasingly sophisticated calculation analysis tools for economic valuation of the reservoir while reducing overall time required to obtain the result. In the final operation, only a small number of full reservoir simulations are required for the most promising FDPs.

The invention relates to a functional resin tectorial membrane proppant and a preparation method thereof, and belongs to the technical field of oil-gas field development. The functional resin tectorial membrane proppant comprises aggregate and a resin film coated on the aggregate. Said resin film comprises organic silicon compounds of one or more active groups of amino, hydroxyl, carboxyl, alkoxyl and hydrosulphonyl. The side chain of the organic silicon compound is a hydrophobic group. The cured resin film has different wetting qualities for oil and water. The functional resin tectorial membrane proppant of the invention has a function of allowing the smooth permeation of oil gas and preventing water from penetrating through the proppant. Such a function improves the separation effect ofoil gas and water and reduces the oil production cost. The excellent hydrophobicity of the resin film facilitates the proppant to have excellent water resisting property and improves the crushing resistance of the proppant, so that the stream guidance effect is good for a long time.

The invention relates to fracturing reformation in the field of oil-gas field development, in particular to a method for optimizing fracture conductivity of a tight gas-reservoir fractured horizontal well. The method mainly comprises the following steps of (1) collecting basic parameters of a reservoir, fluid property and a horizontal well shaft; (2) collecting basic parameters of fractures of the fractured horizontal well; (3) evenly dividing each fracture of the fractured horizontal well into line congruence with equal length along the fracture length direction; (4) building a reservoir permeability model for a tight gas-reservoir fractured horizontal well fracture system; (5) building a flowing decompression model of gas in the fractures; (6) building a flowing model of coupled gas in the reservoir permeability and the fractures, and forming a yield calculation model of the tight gas-reservoir fractured horizontal well; (7) optimizing the fracture conductivity of the tight gas reservoir fractured horizontal well. By utilization of the method for optimizing the fracture conductivity of the tight gas-reservoir fractured horizontal well provided by the invention, the shortages of the prior art can be conquered, and the problem of optimizing non-constant fracture conductivity of the fractured horizontal well along the fracture length direction is effectively solved, so that reasonable basis is provided for the optimization design of reservoir reformation, and the reservoir reformation effect is improved.

The invention belongs to the field of oil and gas field development and relates to a tractor used for drilling, logging and well repair engineering of a coiled tubing and favorable for the coiled tubing to extend into a horizontal well section for a longer distance. A motor-driven underground tractor for the coiled tubing comprises an upper tractor system, a hexagonal central sliding pipe and a lower tractor system, wherein the upper tractor system comprises an upper supporting unit, an upper electric drive and control unit and an upper traction unit; and the upper tractor system and the lower tractor system have the same structure, and are connected at the upper part and the lower part of the hexagonal central sliding pipe respectively in a sleeving way and mounted in the same or opposite direction. The tractor is directly driven and controlled by a servo stepper motor, so that the dependence on liquid energy in the process of driving the tractor by using circulating liquid and the complexity of control of a hydraulic valve of the circulating liquid on a pipeline are reduced and most of space occupied by the hydraulic pipeline is saved; and the tractor can perform dual-direction traction, is good in stability, flexible in traction and fast in traction speed, can be suitable for underground traction work of small well holes, and can guarantee normal underground liquid circulation in the traction process.

The invention, which belongs to the shale gas development field during oil-gas field development, discloses an initial productivity prediction method of a shale gas horizontal well. The method comprises the following steps: establishing a well logging interpretation and construction fracturing parameter database of a shale gas horizontal well; carrying out thickness weighting calculation to obtain relevant single-well geological and engineering parameters; carrying out a multi-factor sensitivity analysis by using an orthogonal test method to determine main controlling factors influencing the productivity of the shale gas horizontal well; and establishing an initial productivity prediction equation of the shale gas horizontal well based on multiple regression linearity and predicting the productivity of a newly-drilled shale gas horizontal well by using the equation as a model. On the basis of comparison of a predicted result and an actual measurement result, the relative error is less than 20%, so that the productivity precondition precision based on the method is high.

The invention discloses a reservoir fracture determining method, which comprises the steps of conducting fracture prediction analysis to actual seismic data through various methods according to types of the actual seismic data to obtain reservoir fracture attribute and distribution; conducting forward modeling by using actual geologic parameters and comparing reservoir fracture distribution by using FMI (Formation MicroScanner Image) data to obtain matching degree and goodness of fit; and according to the matching degree and the goodness of fit, preferably selecting an optimum fracture analysis method from various fracture prediction and analysis methods, and according to the preferably selected fracture analysis method, explaining the actual seismic data to determine reservoir fractures. The reservoir fracture determining method has the advantages that the problem in accurately obtaining reservoir fracture development parameters is solved; the fracture direction and density of fractured reservoirs can be effectively predicted and reliable bases are provided for researches on the fractured reservoirs; and bases are provided and directions are pointed out for work such as oilfield and gas field development plan design of fractured reservoirs, and the exploitation and development risks and costs are decreased.

A roadmap for a field development strategy for optimal recovery is provided in a high quality 3D geological model. This geological model combines geological attributes, pore and rock properties for an optimum 3D representation of the reservoir thousands feet beneath the surface. The model is based on the pertinent geological facies, derived from well core description and detailed studies of rock, as well as fluid and pore properties (Full Pore System) obtained from laboratory analyses of core material and well log data. These data differentiate various important pore throat and pore body regions and relationships, i.e., macroporosity and microporosity. Understanding hydrocarbon volumes in the various pore type groups and then establishing proper recovery techniques through focused laboratory studies yields a field development strategy that can significantly increase hydrocarbon recovery from a reservoir.

The invention discloses a hydrophobic amorphous alloy coating which is prepared by taking Fe-based amorphous alloy powder as a raw material and adopting a supersonic flame spraying technique. The Fe-based amorphous alloy powder is composed of the following elements and inevitable impurities: 10.0-17.0% of Cr, 12.0-20.0% of Mo, 4.0-8.0% of B, 10.0-18.0% of C, 0.0-5.0% of Y and balance of Fe. The invention also discloses a preparation method of the coating. The amorphous alloy coating obtained by the invention not only has better lyophobic property, but also has better corrosion resistance, and high hardness and binding strength, thus having great application prospect on the facilities in the fields of underwater drag reduction, pollution prevention of ship shells, scale prevention on four walls of a boiler, hydraulic power and oil-gas field development and the like.

The invention relates to the field of gas field development research, in particular to a method for predicting dynamic open-flow capacity of fractured horizontal wells for tight sandstone gas reservoirs. The method includes coupling gas reservoirs, fracture and wellbores to obtain gas and liquid two-phase flow productivity equations for optional fracture locations of the fractured horizontal wells; building corresponding fractured horizontal well numerical models on the basis of reservoir stratum parameters and fracture parameters to obtain relation curves and fitting relational expressions of non-dimensional gas release boundaries and gas test time; computing gas release boundaries of the fractured horizontal wells at production phases by the aid of dynamic reserves inverse processes; solving the gas and liquid two-phase flow productivity equations on the basis of phase permeability curves obtained by rock core tests so as to obtain the dynamic open-flow capacity of the fractured horizontal wells at the different production phases. The method has the advantages that influence of difference of physical parameters of reservoir strata, change of the fracture parameters, difference of gas well open-flow test time, external fracturing fluid and movable water of formations on open-flow capacity is taken into consideration, accordingly, the open-flow capacity of the fractured horizontal wells at the different production phases can be predicted by the aid of the method, and the prediction practicality and reliability can be improved.

The invention provides a device and a method for measuring an axial diffusion coefficient of gas in a porous medium and belongs to the field of oil-gas field development. The device comprises a constant temperature oil bath (1), and a holder (2), a container (16) and a high pressure gas cylinder (11) which are arranged in the constant temperature oil bath (1), wherein a lead sleeve (4) is arranged in the holder (2) and is in a cylindrical structure of which two ends are open; a plug (3) is arranged at one end of the lead sleeve (4), and a plug (7) with a valve is arranged at the other end of the lead sleeve (4); an outer cylindrical surface of the plug (3) and an outer cylindrical surface of the plug (7) with the valve are in sealing contact with an inner surface of the lead sleeve (4); a sample cavity is formed in an inner cavity of the lead sleeve (4) between the plug (3) and the plug (7) with the valve; a porous medium (5) is arranged in the sample cavity.

The invention belongs to a method for detecting reservoir fissure development direction in the field of petroleum seismic exploration and oil gas field development, particularly relating to an analytical expression of an included angle between an acquisition system coordinate system and a natural system coordinate system by utilizing multiple wave seismic data, an orthogonality principle formula and an Alford rotation formula; an angle analytical formula inverts the main direction of the fissure and analyzes the fissure development density so as to detect the reservoir fissure development. The angel has a specific physical significance, back calculation is simple and convenient, and an algorithm is not affected by fast and slow shear wave delay time. Even if the polarization of the fast and slow shear wave does not strictly satisfy the relationship of cross polarization, the angle of the inversion angle analytical expression is still within the acceptable error range. The precision of the inversion angle more approaches the real result along with the improvement of the signal to noise ratio of the multi-component data.

The invention relates to a variable high-temperature high-pressure visual rock core model holding device used for studying the mechanism of heightening recovery efficiency in the process of oil-gas field development. The holding device is characterized in that a ceramic electrical heating rod, a temperature sensor and a return control drill way are arranged in a model cabin upper cover. Four fluid channels and a drill way exerting annular pressure are formed in a model cabin base, through holes are formed in the center of the model cabin upper cover and the center of the model cabin base, and silica glass windows are arranged in the through holes. A high-pressure sealed cabin is formed between the model cabin upper cover and the model cabin base, and a quick-connection type pitch varying model holder is arranged in the high-pressure sealed cabin and can rotate freely driven by a high-pressure quick connector. Model cabin heat preservation sleeves are sleeved outside the model cabin upper cover and the model cabin base. The holding device has the advantages that the holding device can be used for carrying out macroscopic and microcosmic visual simulation experiment studies under the oil reservoir condition, the quick-connection type pitch varying holder is variable in pitch row, model specification limits are reduced, due to the four fluid channels, evaluation experiments for a horizontal well, a straight well and other various models can be carried out, the simulation degree is high, and the application rang is wide.

The invention belongs to the field of oil and gas field development, and particularly relates to a water-drive reservoir well network optimization design method. The method adopts the well network and well position two-stage optimization design, and includes the following steps of firstly, finding and arranging reservoir geological development data; secondly, conducting first-stage well network design and determining reasonable well network density and well network mode; thirdly, conducting second-stage well position optimization, and optimizing and fine adjusting well positions of all wells. By means of the method, the reservoir physical property and heterogeneity, the reservoir fluid heterogeneity, the economic factors and the like can be comprehensively considered; by means of the two-stage design method with the first-stage well network design and the second-stage well position optimization, the linked optimization of well network density, well distribution mode and well positions is achieved; the optimization efficiency can be greatly improved for large-scale reservoir.

The invention provides a method and a device for predicting permeability on the basis of pore structures of carbonate rock. According to the method, firstly, the pore structures are classified on thebasis of similarity level of mercury injection curves, then each type of pore structure reservoir is analyzed with a mathematical statistics method, key pore throat size Rs for controlling permeability is identified, and the relation between the key pore throat size Rs and the permeability of each type of pore structure is established, so that the permeability of a highly anisotropic reservoir canbe predicted. According to the provided scheme, microscale and macroscale combination is realized by comprehensively using a core, property testing, mercury injection and well logging, the theoretical basis is firm, the operability is high, and practice proves that the method and the device have good application effect and high applicability to porous-type carbonate rock reservoirs, can effectively predict the permeability of the carbonate rock and have great significance in identification of barriers and interlayers of highly anisotropic carbonate rock as well as design and regulation of oiland gas field development programs.

The invention discloses an artificial sandstone core used in the indoor physical simulation experiment, and belongs to the technical field of oil-gas field development simulation. The artificial sandstone core is prepared from the following raw materials by weight percent: 2-20% of clay, 5-25% of cement, 0-10% of feldspar (not containing 0) and 70-95% of quartz sand. The pore throat structure distribution curve of the core is adjustable, the wettability is adjustable, the pore throat distribution range is wider and capable of representing double-peak distribution, and the pore throat structure is more complex. The substance component in the stratum natural rock is generated through the silicate mixture in the cement and the subsequent treatment so that the component of the artificial sandstone is diverse, the defects that the artificial core pore throat distribution and wettability are much different from those of the natural core are effectively overcome, the natural core can be more accurately and really simulated, the artificial sandstone core is simple in structure and stable in performance and suitable for replacing natural core in the physical simulation.

The invention discloses a combination property experimental device and a performance estimating method for a sand-preventing sieve tube, which belong to the technical field of loose sandstone oil and gas field development. The device comprises a closed main tank body, a simulating well wall sleeve, a simulating casing, a simulating jet hole eyelet and a fastening tie rod; the main tank body comprises a top cover, a barrel side wall and a supporting bottom; the side wall of the main tank body is provided with eight liquid inlets; the supporting bottom is provided with one liquid outlet and seven pressure testing holes; the top cover is provided with two air exit holes and four assembling hanging rings; both the simulating well wall sleeve and the simulating casing are steel barrels with a plurality of eyelets, are nested in the main tank body and are detachable; the simulating eyelet is a plastic short pipe with better flexility; and the fastening tie rod is a specially-made steel bolt. By using the combination property experimental device and the performance estimating method for the sand-preventing sieve tube, sand-preventing well completion conditions, such as the sand prevention and the gravel packing sand prevention and the like of a jet hole, a bare hole and a sieve tube can be simulated; the radial flow state at the bottom of an actual well is simulated; collected data of flow rate, pressure and sand production rate are analyzed; and one set of performance evaluating method for the sand-preventing sieve tube is provided.

The invention provides a novel tough particle strengthened iron-based amorphous composite coating. The mechanical composite powder of iron-based amorphous alloy powder and tough metal powder is used as a raw material, wherein the iron-based amorphous alloy powder consists of the following elements and unavoidable impurities in percentage by atom: 10.0-17.0% of Cr, 12.0-20.0% of Mo, 4.0-8.0% of B, 10.0-18.0% of C, 0.0-5.0% of Y and the balance of Fe; the tough metal powder can be stainless steel powder, nickel-based metal powder, cobalt-based metal powder, aluminum-based metal powder or copper-based alloy powder; the coating is prepared by the high velocity oxy-fuel technology. The iron-based amorphous composite coating provided by the invention has dense structure, low porosity, relatively high toughness and good bonding strength with the metal substrate. The composite coating has great application prospects in the industrial fields such as waterpower and oil-gas field development facilities, pipeline transportation, ship decks and the like.

The invention belongs to the field of magnesium alloy material preparation and oil-gas field development and particularly relates to soluble extrusion magnesium alloy and a preparation method thereof. According to a design formula, metal Al, Mg, Zn, Cu and Ni are weighed for smelting and casting, after an obtained cast ingot is processed into a cylindrical shape, heat treatment is conducted, and finally the target alloy is obtained through hot extrusion. The magnesium alloy prepared through the preparation method is good in crystal morphology, high in mechanical strength, soluble in an aqueous solution containing an electrolyte and suitable for machining a packing tool used in the fracturing transformation process of an oil-gas field. The soluble material is used for manufacturing the packing tool for fracturing, the packing tool can dissolve away voluntarily after being used, so that the subsequent flowback and milling procedures are omitted, and thus the construction efficiency is improved.

The invention provides a synergetic fracturing method for a main crack and a complex crack network of a large channel. The synergetic fracturing method for the main crack and the complex crack network of the large channel is a novel fracturing technique which is in a country road network and highway mode and is applied to the field of oil-gas field development. According to the synergetic fracturing method for the main crack and the complex crack network of the large channel, the channel fracturing technique and the deflection fracturing technique are combined organically, and an implementation method is provided; the synergetic fracturing method is suitable for various conventional and unconventional reservoirs such as high-permeability sandstone, shale, tight sandstone and coal rock, volume transformation of vertical wells and horizontal wells within a wider range is achieved, the flowing ability of fluid in the reservoirs is enhanced, the effective stimulation period is prolonged, and the rate of oil-gas recovery is increased; and meanwhile, the construction cost can be reduced to a larger extent, and the synergetic fracturing method has a positive guiding effect on development of oil and gas resources.