876 results about "Field development" patented technology

Integrated surface-subsurface modeling has been shown to have a critical impact on field development and optimization. Integrated models are often necessary to analyze properly the pressure interaction between a reservoir and a constrained surface facility network, or to predict the behavior of several fields, which may have different fluid compositions, sharing a common surface facility. The latter is gaining a tremendous significance in recent deepwater field development. These applications require an integrated solution with the following capabilities: * to balance a surface network model with a reservoir simulation model in a robust and efficient manner. * To couple multiple reservoir models, production and injection networks, synchronising their advancement through time. * To allow the reservoir and surface network models to use their own independent fluid descriptions (black oil or compositional descriptions with differing sets of pseudo-components). * To apply global production and injection constraints to the coupled system (including the transfer of re-injection fluids between reservoirs). In this paper we describe a general-purpose multi-platform reservoir and network coupling controller having all the above features. The controller communicates with a selection of reservoir simulators and surface network simulators via an open message-passing interface. It manages the balancing of the reservoirs and surface networks, and synchronizes their advancement through time. The controller also applies the global production and injection constraints, and converts the hydrocarbon fluid streams between the different sets of pseudo-components used in the simulation models. The controller's coupling and synchronization algorithms are described, and example applications are provided. The flexibility of the controller's open interface makes it possible to plug in further modules (to perform optimization, for example) and additional simulators.

Method for aligning converted wave seismic reflection data (PS data) with conventional PP seismic reflection data so that both data types may be used to more accurately image the subsurface for hydrocarbon exploration or field development. Amplitude vs. angle (AVA) or amplitude vs. offset (AVO) attributes of PP and PS seismic data are identified and defined, which attributes are theoretically expected to be in phase and optimize seismic resolution in the data. In one embodiment of the invention, such attributes are calculated (310), then the same horizons are identified in a series of PP attributes and in a series of PS attributes, then the second series is aligned with the first at the horizon locations (316, 320), then a time transfer function is generated and applied to the PS mode data (322), and the aligned joint-mode data are inverted (326) using, for example, AVA attributes.

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.

The invention relates to a device and method for testing expanding and percolation characteristics of microfractures of a compact reservoir, belonging to the technical field of oil-gas field development. The device comprises a triaxial rock core holding device, a microfracture expanding pressure system, a microfracture detection system, a percolation displacement system and a percolation data collection system. The method comprises the following steps: (1) applying an axial pressure to a rock core in the triaxial rock core holding device so as to expand microfractures; (2) monitoring development and evolution characteristics of the microfractures of the rock core by virtue of an ultrasonic fault detector, and monitoring deformation characteristics of the rock core by virtue of a stress-strain detection instrument; and (3) testing percolation characteristics of fluid under different microfracture development conditions of the rock core by virtue of a percolation displacement device. The device and the method disclosed by the invention have the beneficial effects that a measurement result is accurate, the assembling is convenient, the operation is simple, the percolation characteristics of oil, gas and water in the microfractures of the compact reservoir can be tested, and the necessary technical support can be provided for fracture development of the compact reservoir.

The invention belongs to the field of oil-gas field development and relates to an experimental evaluation method for fracturing fluid damage in an unconventional tight sandstone oil-gas exploration and development process. The method includes: subjecting fracturing fluid to high-pressure instant reverse injection into a rock core, and simulating flow invasion damages of fracturing fluid in cracks in a continuous extension process after a stratum is fractured by the fracturing fluid; adopting a high-speed centrifuge to set up original water saturation of a reservoir; under the condition of the original water saturation of the reservoir, adopting nitrogen for testing permeability before and after injection of the fracturing fluid into the rock core, and judging fracturing fluid damage degrees according to gas log permeability change rate. By complete simulation of a fracturing fluid injection mode in a fracturing process, adoption of nitrogen for testing permeability accords with seepage characteristics of the tight sandstone gas reservoir, and defects of high experimental displacement pressure, long displacement time, large experimental data errors and the like are avoided.

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.

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 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 relates to a horizontal-well physical simulation experiment device and an experimental method thereof. The horizontal-well physical simulation experiment device is composed of an injection system, a horizontal-well physical simulation device, a mining system and a data analysis and collection system. By adoption of an actual core, different ways of development of a horizontal well can be subjected to dynamic simulation, mining processes such as depletion-driven development, gas-injection huff and puff and displacement, and segmented perforating mining of the horizontal well can be simulated under the condition of high temperature and high pressure of an actual stratum; the actual core can be used in the study of affect of the different ways of the development of the horizontal well upon improvement of a mining rate, and provide of basis for numerical reservoir simulation and field development adjustment of the horizontal well.

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 numerical simulation method of a fractured-vug carbonate reservoir and belongs to the field of oil-gas field development. The method includes: 1, judging whether a representative region of the fractured-vug reservoir has fractures and caves; if not, performing single-pore medium numerical simulation to obtain a mathematical model, and going to the step 6; if yes, going to the step 2; 2, setting dimensional limits l<v1>, l<v2>, l<f1> and l<f2> of intra-medium fractures and caves of the fractured-vug reservoir; 3, according to the determined dimensional limits, dividing a medium region of the fractured-vug reservoir into small-size fractures, medium-size fractures, large-size fractures, small-size caves, medium-size caves and large-size caves according to the fractured-vug sizes l<v> and l<f>; 4, according to medium modelling rules of the fractured-vug reservoir and experimental results of representative elementary volumes, judging whether the representative elementary volumes REV<f> and REV<v> exit; if yes, going to the step 5, and if not, returning to the step 2.

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 relates to a method of predicting steam huff-puff early productivity of a heavy oil reservoir horizontal well and belongs to the field of oil-gas field development. The method comprises the steps of 1) establishing a heavy oil reservoir thermal recovery mathematical model based on percolation theory; 2) establishing a nondimensional productivity curve for the horizontal well; 3) recognizing major factors influential to the nondimensional productivity curve of step 2); 4) drawing a nondimensional productivity chart of the horizontal well; 5) predicting steam huff-puff early oil production of the horizontal well under test based on the nondimensional productivity chart of the horizontal well in step 4). The method of the invention has the advantages that initial multiple regression is performed according to the factors influential to the steam huff-puff productivity of a horizontal well to obtain a formula of calculating maximum daily oil production peak of the horizontal well; the steam huff-puff early productivity of a horizontal well can be predicted conveniently and accurately according to the nondimensional productivity chart provided herein.

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 method for carrying out fracture CT (Computed Tomography) scanning and monitoring on initiation and extension of a large-size volcanic hydraulic fracture, which belongs to the field of volcanic gas reservoir and fracturing during oil and gas field development. The method is characterized in that CT scanning is respectively carried out on a rock sample of a volcanic before and after a hydraulic fracture physical modeling fracture test, and the monitoring on the large-size volcanic hydraulic fracture and intuitive analysis on a fracture initiation and extension rule of the hydraulic fracture can be realized through comparing changes of the rock sample before and after the test. According to the method provided by the invention, a fracture initiation and extension process of each scanning cross-section fracture can be clearly and intuitively reflected under the situations of different primary stress differences before and after fracturing, rock pore, development degree of a natural fracture and discharge capacity and viscosity of a fracturing liquid, and an important role is played in researching a fracturing fracture initiation and extension mechanism which adapt to characteristics of multiple fractures and fractured-vuggy reservoir of the volcanic.

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 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.