354 results about "Material balance" patented technology

The invention relates to a method and system for establishing a multilayer oil pool inter-well connectivity model. The multilayer oil pool inter-well connectivity model capable of simulating oil and water dynamic states is established oriented to the limitation that by means of a current connectivity model, only the dynamic change of production liquid can be predicted, the dynamic states of the oil phase and the water phase cannot be calculated respectively, and connectivity analysis cannot be carried out layer by layer. According to the model, an oil pool system is layered and scattered into a series of inter-well communication units, matter balance equation calculation is carried out with the inter-well communication units as simulating objects, pressure solving and inter-well flow calculation are achieved, an inter-well saturation degree tracking calculating method is established with the combination of the lead edge boosting theory, and the output dynamic states of oil and water of all layers at well points are obtained; a model parameter inversion method is established in a fitting mode through dynamic states based on a random disturbance approximation method, a projection gradient method and the like. Layered inter-well flow distribution coefficients, single well longitudinal production liquid and production oil splitting coefficients and other information can be obtained in real time, the oil pool plane, the longitudinal oil and water flow relation and the production measure change can be more accurately reflected to guide the practical production of an oil field.

The invention discloses a method and a system used for determining well control dynamic reserves of a shale gas well. The method comprises the steps of obtaining an initial formation pressure of a shale gas reservoir, and calculating a well bottom flow pressure through structure data and production data of the gas well; establishing a first interpolation table based on a conversion relationship between a pressure and a pseudo-pressure to establish a corresponding relationship between the pressure p and the pseudo-pressure m(p); establishing a second interpolation table based on given basic parameters and Za(p) defined by a matter balance equation of the shale gas reservoir to establish a corresponding relationship between the pressure p and a ratio of the pressure p to Za(p); and based on the initial formation pressure, the well bottom flow pressure and the production data, determining the well control dynamic reserves of the shale gas well by adopting the first interpolation table, the second interpolation table and a productivity equation. According to the method and the system, a shut-in pressure is not needed to recover an evaluated average formation pressure in calculation; and a calculation result is suitable for various applications such as reasonable shale gas well production allocation, reasonable development technology policy making, development scheme optimization and the like.

The present invention provides a method for calculating a dynamic reserve of a dense oil fractured horizontal well, and relates to the technical field of dense oil fractured horizontal wells. The method comprises: dividing a dense oil fractured horizontal well into a first percolation region and a second percolation region; dividing a production process of the dense oil fractured horizontal well into a first stage and a second stage; calculating a first average formation pressure of the first percolation at each time in the first stage, and calculating a second average formation pressure of the first percolation region and a third average formation pressure of the second percolation region at each time in the second stage; according to a pre-established mass balance equation, determining a dynamic reserve of the first percolation region in the first stage as a dynamic reserve of the dense oil fractured horizontal well of the first stage; and according to the pre-established mass balance equation, determining a dynamic reserve of the first percolation region and a dynamic reserve of the second percolation region in the second stage, and determining a sum of the dynamic reserve of the first percolation region and the dynamic reserve of the second percolation region to be a dynamic reserve of the dense oil fractured horizontal well in the second stage.

A method for continuously determining characteristics of a process fluid includes inline real-time analysis. In one embodiment, inline analysis of water, oil, and salt anions provides continuously obtained measurements for determination of various drilling fluid properties and assessment of drilling operation parameters and wellbore conditions. In one embodiment, the continuously provided measurements and / or data calculated therefrom allow for monitoring and controlling of a downhole drilling operation. In embodiments of the method, automated control of drilling operations using the continuously generated information can be accomplished. In one embodiment, a material balance of drilling fluid components using the continuously generated information is provided.

The invention relates to a method for controlling and optimizing the distillation tower. It controls the distillation tower in dependence on the material balance relation and component balance relation, optimizes the distillation tower by using representative model. Employing the abstraction proportion between the light product on the top of the tower and heavy product in the bottom of the tower (in following, taking the proportion between light and heavy product for abbreviation) as main controlled variable depending on the distillation principle, the material balance and component balance in the distillation tower, controlling the proportion between the light and heavy product, temperature, reflux ratio to realize stable operation by regulating the quantity of reflux and heat load of re-boiler. Simulating the practical course through the technological process simulation software, and training the nerve net model to become the representative model for the course optimization. Optimizing the operation with the representative model by using the analytical data for the raw material and product to realize the product Ka bian optimization, increasing the productivity of product with high value on the condition of guaranteeing the product quality and realizing the device energy saving and consumption reduction.

Methods and systems for modeling a reservoir system are described. The method includes constructing a reservoir model of a reservoir system. The reservoir model includes a reservoir and a plurality of wells. Also, one or more material balance groups are constructed with each material balance group having a portion of at least one of the plurality of wells, a portion of the reservoir, and at least one well management algorithm to track material balance within the respective material balance group. Then, fluid flow through the reservoir model is simulated based on the material balance groups by a simulator and the results are reported.

The invention provides a low-permeability gas reservoir dynamic reserves evaluation method, and belongs to the field of the low-permeability gas reservoir dynamic reserves evaluation method. The gas well dynamic reserves is the important evidence for gas well reasonable production allocation and development scheme customization. Since the low-permeability gas reservoir stratum is bad, and the suitable condition of the dynamic reserves computation method of the traditional pressure drop method and pressure recovery well testing method is harsh, and needs the complex correction. By improving thesubstance balance method reserves computation way, a harmonic decline curve model is imported, and a relation curve of a gas productivity index to fitting time is drawn on the double-logarithm coordinate so as to be fit with the harmonic decline curve on the Fetkovich plate, thereby establishing a fitting point, and solving the stratum parameter in the premise of not performing the full gas-reservoir shut-in. The advantage of the computation method is that the gas well does not to perform the shut-in manometry, the reservoir computation can be directly performed by directly applying the gas well production data without influencing the gas well production, and the method has extensive practicability.

The invention relates to an electricity storage management technology, in particular to a team and group integrated operation management system based on storage ERP (enterprise resource planning). According to the system, second-level warehouses of an electric system are subjected to intelligent operation management on the basis of a team and group storage ERP system; operating data such as ex-warehouse, warehouse entry, allocating, checking and the like of equipment are correlated by taking data input by RFID (radio frequency identification) as basis and a unique identification code of the equipment as a correlation point, and effective storage management master data are formed finally; various data in the master data are processed by conventional graph generation software to generate a required analysis report or data report which is visually displayed to a manager, the manager masters warehouse materials, machine accounts and the like conveniently, effectively and timely, so that the warehouse materials can be supplemented and adjusted, the management efficiency is greatly improved, account and material coincidence is guaranteed, material balance is achieved, and fund waste is avoided.

The invention discloses a combined measurement method for organic matter-rich compact rock core gas permeability and diffusion coefficient. The method utilizes a gas pressure attenuation device to accomplish. The device is composed of a rock core holder, a gas storage chamber, a vacuum pump, a confining pressure pump, and a computer. The rock core holder is connected to the vacuum pump and the confining pressure pump respectively, the inlet end of the rock core is connected to the gas storage chamber and a gas source, the outlet end of the rock core is in a closed state, and the device is located in a water-bath heating system. By monitoring the process of the gas in the gas storage chamber flowing to the rock core till balance, a gas pressure attenuation curve can be obtained, then according to a real gas state equation, material balance and the occurrence and flow mechanism of gas in rock, the attenuation curve is divided into a seepage stage and a diffusion stage, thus acquiring the gas permeability and diffusion coefficient. The method provided by the invention simplifies the testing procedure, improves the experimental analysis efficiency, and can provide data support for experimental evaluation of gas mass-transfer ability in shale, coal rock and other unconventional reservoir rocks, gas well productivity prediction and the like.

The invention discloses a method for measuring a gas and water relative permeability curve through coal-bed gas well production data. Average reservoir pressure and average water saturation are obtained with a material balance method, and therefore changes between absolute permeability and relative permeability can be obtained; changes of irreducible water saturation are predicted through the relation between irreducible water saturation and porosity; the absolute permeability and the relative permeability generated after end points are calibrated are coupled in the same state, a domain average effective permeability dynamic prediction model can be obtained, and an effective permeability curve can be obtained. The method solves the problem that in a laboratory, the relative permeability curve can not be accurately measured easily. Compared with the prior art, the positive and negative effect of a coal reservoir can be well reflected, the gas phase effective permeability can be effectively improved, and a powerful basis is provided for accurately predicting a gas and water output law of a coal-bed gas well and predicting future yield of a producing well.

The invention discloses a method for calculating a non-steady state yield of a volume fractured horizontal well of a shale gas reservoir. The method comprises the following steps of dividing the reservoir into a volume fractured region and a non-transformed matrix region, and collecting basic parameters of the volume fractured region, the non-transformed matrix region and the horizontal well, wherein the volume fractured region is Darcy flow, and the non-transformed matrix region is Knudson flow; according to a mass conservation law, establishing a steady-state yield formula of the volume fractured horizontal well of the shale gas reservoir; based on a pressure propagation formula, the steady-state yield formula and a matter balance equation, calculating the non-steady state yield of the volume fractured horizontal well of the shale gas reservoir by applying a continuous quasi-steady method; and repeating the previous step, and performing calculation to obtain the non-steady state yield of the volume fractured horizontal well of the shale gas reservoir. The method fully considers a process that a pressure is propagated to a boundary gradually in a production process of the volume fractured horizontal well of the shale gas reservoir, different seepage laws of shale gas in a volume transformation region and the non-transformed matrix region, and adsorption and desorption effects of the shale gas, so that actual conditions are better met.

The invention provides an oil and gas well technical recoverable reserves prediction method. The method comprises: collecting daily output and accumulated output data; according to the daily output and accumulated output data, drawing a daily output and material balance time relation curve, the material balance time being ratio of accumulated output and daily output in corresponding time, then, through taking a derivative of the daily output and material balance time relation curve, drawing a feature segment, the feature segment being a segment whose slope is a special value; according to the distribution condition of the feature segment in the daily output and material balance time relation curve, determining a flow filed type, and then according to the flow filed type, establishing a corresponding production decline analysis model; finally, under a set constraint condition, according to the production decline analysis model, predicting technical recoverable reserves. In the method, the production decline analysis model is unified in the same decision rule, and analysis and selection of adaptability of the production decline analysis model are performed through flow field identification, so as to predict technical recoverable reserves. The method can solve technical problems in the prior art that a prediction result is not determined caused by blindly choosing a model, and the method improves prediction precision of the technical recoverable reserves.

An online monitoring method and device for a fossil fuel converter apparatus. The method monitors fuel compositions in real time by measuring operating data of the converter apparatus and comprises the following steps: determining reactant compositions and number of variables thereof; determining fuel compositions and number of variables thereof; determining compositions of incomplete products and number of variables thereof; determining relationship between the fuel compositions and calorific value; establishing an equation set involving the fuel compositions, the reactant compositions and the resultants compositions, according to energy balance relationship and material balance relationship in the combustion process; providing given conditions for independent relationships concerning variables in the above equation set; measuring boiler operating data and assigning the variables in the above equation set; and finding the solution to the equation set and obtaining real-time monitoring data of the converter apparatus.

The invention discloses a method for recovering CO from a high-pressure acetic acid tail gas produced by carbonylation through a membrane process and a device thereof. The tail gas is treated by three steps, that is, pretreatment, membrane separation and gas compression: the tail gas that passes a gas washing tower, a demister and a combined filter enters a Prisen membrane separator through a heater, the tail gas after the membrane separation enters a compressor, a product gas is recovered and reused, and hydrogen rich gas flows to a torch for burning. In the method, two Prisen membrane systems help control the amount of the feed gas entering a membrane, the product gas and the hydrogen rich gas to reach N2 material balance, ensure the CO recovery rate and achieve the purpose of the long and stable operation of a membrane separation device; and the content of the CO in the final product gas is not less than 91%.

The invention discloses a method used for determining shale-gas multistage-fracturing horizontal-well interior-and exterior-zone dynamic reserves. The method includes: establishing gas-well binomial productivity equation through gas testing materials, and calculating actual flowing bottomhole pressure (FBHP) through production data and gas-well structure parameters; respectively establishing matter balance equation of a fracturing transformation zone and a non-fracturing transformation zone for a multistage-fracturing horizontal well in considering of adsorption gas desorption and abnormal high pressure influence; respectively setting the dynamic reserves of the fracturing transformation zone and the non-fracturing transformation zone, adjusting the dynamic reserves by combining with the matter balance equation of the fracturing transformation zone and the non-fracturing transformation zone, interporosity flow equation between the fracturing transformation zone and the non-fracturing transformation zone and the binomial productivity equation, and determining the fracturing horizontal-well interior-and exterior-zone dynamic reserves. With the method, testing of average formation pressure by well shutdown is not needed during use, influence of adsorption gas desorption and abnormal high pressure as well as fracturing recombination zones can be considered, and the dynamic reserves of the fracturing transformation zone and the exterior non-fracturing transformation zone can be respectively determined.

The invention provides a method for treating hydrochloric acid leachate of ferrotitanium materials. The method comprises the following steps of: dividing and burning leached mother liquid which is obtained by leaching the ferrotitanium materials by using hydrochloric acid leaching liquid; recovering hydrogen chloride obtained by burning for regeneration and cyclic utilization of the leaching liquid. By the method provided by the invention, the leachate is divided according to material balance of the leach elements (mainly comprising iron) of the hydrochloric acid leachate; and one part of theleachate after division is burned and the other part of the leachate is directly or indirectly absorbed by the hydrochloric acid to return to the leaching procedure, so that completely closed circuitcirculation is formed. By the method provided by the invention, the defect of overlarge energy consumption in the burning procedure after the ferrotitanium materials are leached by the conventional hydrochloric acid can be overcome and the burning quantity of the leached mother liquid can be reduced by 40 to 55 percent, so that the energy consumption of the whole process can be reduced by 35 to 45 percent. The method has a good industrial application prospect.

The invention discloses a marine sniffing estimation method of sulphur content in fuel oil, comprising the following five steps: acquiring tail gas; drawing a SO2 monitoring curve and a CO2 monitoringcurve to acquire SO2 concentration value, CO2 concentration value, SO2 background concentration value and CO2 background concentration value during the same monitoring period; calculating sulphur content in marine fuel oil on the basis of material balance; acquiring monitoring time of ships with excessive sulphur content in fuel oil; and locking the ships with excessive sulphur content in fuel oil. By the marine sniffing estimation method of sulphur content in fuel oil, the purpose of identifying ships with illegal use of high sulphur oil can be achieved without going on board, and huge wastecaused by blind sampling is avoided. The invention provides an efficient means for accurate sampling inspection of ships in national ship emission control areas.

The invention discloses a method for simulating water injection well water pressure drive fracture extension dynamic. The method comprises the following steps that an oil reservoir geological characteristic parameter of a target water injection well with fractures is obtained according to the oil reservoir geological study; a water injection well water pressure drive hydraulic fracture extended model is established with the integration of a Darcy leak-off model, a continuity equation, a matter balance equation and an initial condition; fluid volume filtered into a stratum is used as a source item based on an oil-water two-phrase seepage model of a seepage mechanics theory, the boundary condition is established by combining the fluid pressure in the fracture, a hole elastic deformation relationship between a fluid body and a rock is established by being combined with a boundary condition established by the fluid pressure in the fracture, that is, a fluid-solid coupling model is established, and the formation pore pressure is calculated and strain and a pore penetration change which are caused by a change in the fluid pressure are obtained; and then the fracture extension dynamic after the action of the fluid-solid coupling is obtained, then the obtained new parameter is used as an initial condition to be repeated, and finally the fracture extension dynamic is obtained. Accordingto the method for simulating the water injection well water pressure drive fracture extension dynamic, the dynamic extension condition of the fracture in a water injection well and the dynamic changecondition of the parameter in a reservoir can be forecasted according to the construction and geological parameters.

The invention relates to a compacted oil source rock classification evaluation standard division method based on hydrocarbon expulsion efficiency, which belongs to the field of unconventional oil and gas exploration and development. The method comprises the following steps: 1) the hydrocarbon generating quantity of a hydrocarbon source rock is evaluated based on a chemical dynamics method; 2) recovery of the original residual hydrocarbon quantity (S1) in the hydrocarbon source rock is carried out; 3) the hydrocarbon expulsion quantity (the hydrocarbon expulsion quantity=the hydrocarbon generating quantity-the residual hydrocarbon quantity) of the hydrocarbon source rock is evaluated based on a material balance method; 4) overpressure history recovery of the compacted oil source rock is carried out; and 5) the relationship between the hydrocarbon expulsion quantity and geological and geochemical parameters of the hydrocarbon source rock is built, and classification evaluation standards are defined. The invention provides a systemic and manipulable compacted oil source rock classification evaluation standard definition method with a strict scientific basis, and based on the method, classification evaluation on the compacted oil source rock can be realized, and a quality source rock distribution area can be depicted.

The present invention discloses a shale oil and gas integration output analysis method based on a dynamic leakage flow volume. The method comprises: arranging and preparing data; preliminarily estimating a limit leakage flow volume and effective fracture half-length, and calculating a dynamic leakage flow volume, a reservoir average pressure change and pressure correction factors; drawing an output normalization pseudopressure curve, calculating a fluid diffusion coefficient in a fracture reconstruction area, drawing a square root time characteristic curve, calculating the effective fracture half-length, and determining the limit leakage flow volume and the final output degree according to the correction Duong method; if the effective fracture half-length and the limit leakage flow volume calculation value are very different from an input value, substituting the calculation value into the step 2 again to perform circulation until the convergence is consistent so as to obtain the accurate effective fracture half-length and the limit leakage flow volume; substituting a dynamic leakage flow volume formula into a macroscopic material balance model, and performing comparison to obtain the accumulation contribution of the size of the fracture reconstruction area to the shale oil and gas production; and determining an optimal fracture horizontal well fracture interval and an optimal well spacing. The shale oil and gas output dynamic analysis and evaluation accuracy is improved.

The invention discloses a control system for an electrolysis cell, and particularly relates to an aluminum electrolysis cell region control system for regionally controlling material balance, anode current distribution and aluminum electrolyte interface stability of a pre-baked anode aluminum electrolysis cell by using a region control method and an aluminum electrolysis cell region control method. The system comprises the electrolysis cell and a cell control machine; the electrolysis cell is divided into two or more control regions; and a signal acquisition and processing subsystem, a cell condition diagnosis subsystem, a regional alumina feeding subsystem and a regional polar distance control subsystem are arranged in each control region. The system and the method have the advantages of controlling each control region of the electrolysis cell with pertinence, improving the control precision, performing effective monitoring and separate region control on the abnormal regions, preventing the integral operation from destroying the state of the electrolysis cell, particularly heat balance, facilitating stable electrolysis cell operation, and achieving the effects of saving energy, reducing consumption and improving current efficiency.

A fracture-vug type carbonate reservoir water breakthrough early warning method of the present invention relates to an oil well water breakthrough early warning method, and aims to determine the water invasion time timely, optimize a working system, prolong an oil well water-free oil production period, and improve the oil well recovery efficiency. The method of the present invention comprises the following the steps of S01 obtaining the oil pressure drop under different accumulative liquid volumes according to a matter balance equation, and drawing a relational graph of the oil well pressure drop and the accumulative liquid volume; S02 for the non-water breakthrough reservoir, if a oil well pressure drop and accumulative liquid volume curve deviates, explaining three possible phenomena: (1) the crude oil is degassed in a shaft or stratum; (2) a new reservoir is exploited; (3) the edge-bottom water begins to invade; S03 excluding the two situations that the crude oil is degassed in the shaft or stratum and the new reservoir is exploited to determine that the reservoir edge-bottom water begins to invade; S04 determining the water invasion time according to the relational graph of the oil well pressure drop and the accumulative liquid volume, and carrying out the water breakthrough early warning.

The invention discloses a method for optimizing gasoline blending in an offline manner. The method includes building a gasoline blending model; optimally computing the built model by the aid of a particle swarm optimization algorithm. The minimum blending cost, the minimum product mass surplus and the minimum manganese-additive dosage are comprehensively taken into consideration in the model on the premise that requirements of product index constraints, component inventory constraints, manganese-additive dosage limit and material balance constraints are met. The method has the advantages that equality constraints in the blending model are processed by the aid of the particle swarm optimization algorithm in a novel processing mode, so that a result obtained after particle swarms are updated at every turn can assuredly meet conditions of the equality constraints, the scale of population can be guaranteed, and the arithmetic speed can be increased.

The invention discloses an effluent index online soft measurement prediction method in the urban sewage treatment process. According to the method, firstly an instant learning model structure with correlation as the principle and the recursive partial least-square method as a local model is adopted, and meanwhile, description on uncertainty of the model is performed on the basis of the statistical learning theory. The model can be used for fully reflecting the characteristics such as uncertainty and large lag of the sewage treatment process, the explanatory performance of a prediction result is higher, controllers can adjust process variables such as the aeration rate and the backflow amount of an aeration tank in time, material balance and bacterial population balance are kept, and efficient removal of organic matter is achieved fully.

Lumping and delumping method for estimating the properties or the behaviour of liquid and / or vapour hydrocarbon phases from data relative to a reference set consisting of hydrocarbon mixtures in a series of thermodynamic states in a medium. Each one of said hydrocarbon mixtures is grouped into at least three constituents (V, I, H), considering that the gas phases resulting from separation under conditions referred to as surface conditions of each mixture do not contain (H) and that the oil phases under the same conditions do not contain (V). The compositions of the separation products comprising, for the gaseous products, at least V and I in variable proportions and, for the liquid products, at least I and H in variable proportions, are determined by material balance. The at least three-constituent composition of each hydrocarbon mixture of the reference set is then determined by combination of the products resulting from the separation thereof in proportion to the amounts of each separation product. Delumping can then be performed to predict, as a function of time and in at least one thermodynamic zone, a detailed composition of a fluid in the medium. Application: hydrocarbon reservoir fluids for example.

The present invention provides an ultra-high pressure gas reservoir production dynamic abnormal data diagnosis and correction method. The linear relationships between high-pressure stage normalization pseudo-pressure p and pressure p, and between high-pressure stage normalization pseudo-pressure p and apparent formation pressure p / z are adopted, the normalization pseudo-pressure yield qg / Delta p and substance balance pseudo-time t<ca> in Pslacio-Blasingame and Agarwal-Gardner decline curves are simplified, a standard flow characteristic curve of an ultra-high pressure gas well is established; the actual production curve of the ultra-high pressure gas well is compared with the standard flow characteristic curve of the ultra-high pressure gas well, so as to judge whether the actual production curve of the ultra-high pressure gas well is abnormal or not and judge the causes of abnormity. The calculation process of the established standard flow characteristic curve of the ultra-high pressure gas well is simple and the work load is small, and the calculation process facilitates on-site application; establishment of the ultra-high pressure abnormal well well-bottom flow pressure tracking and correction method considers the effects of change in the number of the communicated gas reservoir production wells and the gas well production adjustment on well controllable reserves, and thus the forecast result error is reduced.

An optimizing control method for the biologic treating system of sewage features that starting from the technological parameters of the sewage treating system, the kinetic parameters of sewage, the minimal volume of reactor, the materials balancing principle, Monod equation and the circulating variables including BOD content, biomass concentration and returned amount are used to create a mathematical model for the sewage treating technology.

A method for estimating cathode inlet and cathode outlet relative humidity (RH) of a fuel cell stack. The method uses a model to estimate the high frequency resistance (HFR) of the fuel cell stack based on water specie balance, and also measures stack HFR. The HFR values from the estimated HFR and the measured HFR are compared, and an error between the HFR values is determined. An online regression algorithm is then utilized to minimize the error and the solution of the regression is the RH profile in the stack including the cathode inlet and outlet relative humidities.

The invention discloses a water drive reservoir natural water invasion, water injection and production balance state determining method comprising the following steps: acquiring a reservoir average single-well fluid productivity index and a reservoir average single-well water injectivity index; acquiring the maximum bottom hole flowing pressure of the reservoir water injection well; determining the reservoir water injection rate, the reservoir water influx and the reservoir liquid production capacity; determining the relation of the natural water influx, water injection rate and liquid production capacity under the condition of production balance based on the principle of material balance; and drawing a water invasion, water injection and production balance curve based on the principle of material balance, and finding out the 'balance point' of the reservoir. According to the invention, the relational expression which must be met for the realization of stable output of a reservoir along with the increase in water content is calculated out, and a theoretical basis is laid for reservoir stable output analysis. The production pressure difference, average pumping well bottom hole flowing pressure and reservoir pressure level required for the realization of stable output of an instance reservoir in different water cut periods in the future under different well spacing densities and different injector-to-producer ratios are analyzed, and the result provides a technical support for efficient and reasonable development of water drive reservoirs.