193 results about "Gas oil ratio" patented technology

The present invention provides an apparatus and method for high resolution spectroscopy (approximately 10 picometer wavelength resolution) using a tunable optical filter (TOF) for analyzing a formation fluid sample downhole and at the surface to determine formation fluid parameters. The analysis comprises determination of gas oil ratio, API gravity and various other fluid parameters which can be estimated after developing correlations to a training set of samples using a neural network or a chemometric equation.

The present invention provides a sample tank having a window for introduction of electromagnetic energy into the sample tank for analyzing a formation fluid sample down hole or at the surface without disturbing the sample. Near infrared, mid infrared and visible light analysis is performed on the sample to provide a downhole in situ or surface on site analysis of sample properties and contamination level. The onsite analysis comprises determination of gas oil ratio, API gravity and various other parameters which can be estimated by a trained neural network or chemometric equation. A flexural mechanical resonator is also provided to measure fluid density and viscosity from which additional parameters can be estimated by a trained neural network or chemometric equation. The sample tank is pressurized to obviate adverse pressure drop or other effects of diverting a small sample.

A method for determining properties of a formation fluid including obtaining data related to an optical density at a methane peak and an optical density at an oil peak for a fluid sample at a plurality of times, calculating an apparent gas-oil-ratio of the sample fluid from the optical density of the fluid sample at the methane peak to the optical density of the fluid sample at the oil peak at each of the plurality of times based on the data, selecting a power function of a sampling parameter for a buildup of the apparent gas-oil-ratio, calculating an exponential constant of the power function based on the data, and determining at least one selected from the group consisting of a contamination free gas-oil-ratio and a percent contamination.

The present invention describes a unique method and apparatus for applying near-infrared spectroscopy to estimate weight percent of methane in crude oil from which one can then infer gas-oil ratio (GOR) of crude oils downhole in real time while collecting a fluid sample. The correlation equations provided by this invention use two wavelengths, one centered at 1670 and the other centered at 1682 nm. Both wavelengths are primarily sensitive to the methane peak absorption. To significantly improve the fit, non-spectroscopic parameters, such as temperature or pressure, can be included in the correlation equation. Also, this invention can be used to monitor sample cleanup by monitoring the increase in GOR associated with cleanup as a fluid being pumped from the formation transitions from mostly gas-free filtrate to mostly gas-containing crude oil.

The invention relates to a dynamic reserve calculation method and system for a fracture and cave type carbonatite oil reservoir fracture and cave unit. The method comprises a fracture and cave unit type division step, a material balance equation simplification step and a dynamic reserve calculation step. According to the method, firstly, the driving types of the fracture and cave unit are divided according to the communication relationship between the fracture and cave unit and a water body; then, a simplified material balance equation is obtained according to different driving types; then, the dynamic reserve calculation parameters in the material balance equation are optimized by combining production dynamic data through the combined relationship of the ground crude oil density, the natural gas relative density and the gas-oil ratio and the relationship between the elasticity modulus and the porosity; and the dynamic reserve in the dynamic reserve calculation parameters is calculated. The method and the system have the advantages that the precision and the accuracy of the dynamic reserve calculation result are improved; and the basis is provided for the oil reservoir development and exploration and the engineering layout.

A method for determining properties of a formation fluid is provided and includes: obtaining fluid data related to Carbon-Hydrogen molecular bonds in C6+ from a fluid analyzer; and considering the fluid data to calculate mass fractions of hydrocarbon flowing through the fluid analyzer. The method further includes computing gas-oil-ratio of hydrocarbon based on the mass fractions of hydrocarbon. Another method for determining a gas-oil-ratio of a formation fluid includes: obtaining fluid data related to Carbon-Hydrogen molecular bonds in C6+ from a fluid analyzer; considering the fluid data to derive mass fractions of gas and oil; and computing gas-oil-ratio of hydrocarbon based on the derived mass fractions.

The invention relates to an experimental evaluation method of gas-injection displaceable oil of fracture-cave type carbonate reservoir. The method comprises the following steps in sequence: (1) making a fracture-cave type carbonate core model; (2) preparing an in-place oil sample and injected gas, and setting a pressure point p1 for gas injection and a pressure point p2 for gas injection termination; (3) recovering the original state of the core; (4) carrying out an exhaustion experiment from the top end of the core; (5) carrying out the gas-injection displaceable oil experiment for a plurality of times from the top end of the core at the formation temperature; and (6) calculating development indexes (of the gas injection displaceable oil experiment) such as the recovery efficiency of the raw oil, the gas-oil ratio, the gas-water ratio, and the like. By making a physical single fracture plane overall-diameter fracture-cave core model which keeps the completeness of the core, an experimental testing method for physical gas injection displaceable oil simulation is established, and a tool and a means for evaluating the recovery effect of the fracture-cave type carbonate is provided.

The present invention provides a simple, robust, and versatile high-resolution spectrometer that is suitable for downhole use. The present invention provides a method and apparatus incorporating a spinning, oscillating or stepping optical interference filter to change the angle at which light passes through the filters after passing through a sample under analysis downhole. As each filter is tilted, the color or wavelength of light passed by the filter changes. Black plates are placed between the filters to isolate each filter's photodiode. The spectrometer of the present invention is suitable for use with a wire line formation tester, such as the Baker Atlas Reservation Characterization Instrument to provide supplemental analysis and monitoring of sample clean up. The present invention is also suitable for deployment in a monitoring while drilling environment. The present invention provides a high resolution spectometer which enables quantification of a crude oil's percentage of aromatics, olefins, and saturates to estimate a sample's gas oil ratio (GOR). Gases such as CO₂ are also detectable. The percentage of oil-based mud filtrate contamination in a crude oil sample can be estimated with the present invention by using a suitable training set and chemometrics, a neural network, or other type of correlation method.

The present invention provides an apparatus and method for continuously monitoring the integrity of a pressurized well bore fluid sample collected downhole in an earth boring or well bore. The CDR continuous by measures the temperature and pressure for the down hole sample. Near infrared, mid infrared and visible light analysis is also performed on the small amount of sample to provide an on site analysis of sample properties and contamination level. The onsite analysis comprises determination of gas oil ratio, API gravity and various other parameters which can be estimated by a trained neural network or chemometric equation a flexural mechanical resonator is also provided to measure fluid density and viscosity from which additional parameters can be estimated by a trained neural network or chemometric equation. The sample tank is overpressured or supercharged to obviate adverse pressure drop or other effects of diverting a small sample to the CDR.

The invention discloses a retrograde condensation damage experimental evaluation method for a depletion type development near-wellbore zone of a saturated condensate gas reservoir; the method comprises: (1) placing a core in a core holder, and evacuating; (2) increasing oven temperature to gas reservoir formation temperature T0 for 10 hours; establishing irreducible water saturation by using dry gas displacement; (3) injecting dry gas into the core until the pressure of the entry end of the core reaches original formation pressure; (4) injecting condensate gas into the core until gas-oil ratio GOR tested at the exit end of the core is consistent to GOR0, and carrying out condensate gas test under corresponding conditions to obtain gas permeability K0; (5) starting a depletion experiment, recording core exit end pressure Pi and flow Qi, and testing gas permeability Ki of condensate gas under the corresponding pressure condition; (6) drawing a relational curve for core exit pressure and permeability decrease degree. The method has reliable principle, is simple to perform, makes up the defects of conventional retrograde condensation test methods, and has a promising market prospect.

The invention discloses a method for controlling interval pumping of an oil well, which comprises the following steps of: generating a pump dynamograph of the oil well according to a ground indicator diagram of the oil well and basic parameters of the oil well, wherein the basic parameters include a water content parameter of the oil well, a gas oil ratio, a viscosity, a stem diameter, a stem length, a pump diameter, a pump depth and the like; and controlling the interval pumping of the oil well according to the pump dynamograph. The invention further discloses a system for controlling the interval pumping of the oil well, which comprises an acquiring module, a ground indicator diagram generation module, a pump dynamograph generation module and an interval pumping control module. With thesystem and the method for controlling the interval pumping of the oil well, the optimal interval extraction starting point and interval extraction time can be analyzed in real time in combination with the oil production law of the oil well, remote intelligent self dynamic interval pumping control of the oil well is implemented, and consequently energy for the oil well is saved, consumption of theoil well is reduced and loss of operating apparatuses is also reduced.

The invention discloses a carbon dioxide foam stabilizer suitable for low-permeability oil deposit, which is prepared from modified guargum, hydroxyethyl cellulose and lauryl alcohol, wherein the mass ratio of the modified guargum to the hydroxyethyl cellulose to the lauryl alcohol is 4 to 1 to 1. The invention is used for enhancing the stability of carbon dioxide foams, thereby the carbon dioxide foam stabilizer can plug a test well gas channeling passage, improve gas suction and a liquid generating section plane, reduce the gas-oil ratio, solve the problem of gas channeling emerged from low-permeability oil deposit gas injection development and provide technical support for the low permeable oil deposit gas injection development.

The present invention provides a simple, robust, and versatile high-resolution spectrometer that is suitable for downhole use. The present invention provides a method and apparatus incorporating a spinning, oscillating or stepping optical interference filter to change the angle at which light passes through the filters after passing through a sample under analysis downhole. As each filter is tilted, the color or wavelength of light passed by the filter changes. Black plates are placed between the filters to isolate each filter's photodiode. The spectrometer of the present invention is suitable for use with a wire line formation tester, such as the Baker Atlas Reservation Characterization Instrument to provide supplemental analysis and monitoring of sample clean up. The present invention is also suitable for deployment in a monitoring while drilling environment. The present invention provides a high resolution spectometer which enables quantification of a crude oil's percentage of aromatics, olefins, and saturates to estimate a sample's gas oil ratio (GOR). Gases such as CO2 are also detectable. The percentage of oil-based mud filtrate contamination in a crude oil sample can be estimated with the present invention by using a suitable training set and chemometrics, a neural network, or other type of correlation method.

The invention provides a heavy oil reservoir artificial bubble oil throughput exploiting method. The method comprises the following steps of step 1, injecting solvent type foam liquid into an oil well; step 2, after the well is covered for proper time, opening the well to produce oil; step 3, when the daily oil yield is 1m<3>/d to 2 m<3>/d, stopping throughput production of the period, and repeating the step 1 to step 3, and when the gas yield is gradually reduced and the cycle produced gas-oil ratio is smaller than 5, performing step 4; step 4, injecting an oil-soluble viscosity reducer into the oil well; step 5, injecting a solvent type foaming agent into the oil well; step 6, after the well is covered for proper time, opening the well to produce oil; step 7, when the daily oil yield is 1m<3>/d to 2 m<3>/d, stopping throughput production of the period, and repeating the step 4 to step 6; step 8, when the cycle oil yield is smaller than 100 to 200m<3>, stopping production. By the exploiting method provided by the invention, the viscosity of crude oil can be greatly reduced, and the aim of greatly improving the primary gas-containing heavy oil reservoir recovery ratio is fulfilled due to the fact that bubble oil flow is artificially produced.

The invention relates to a physical simulation huff-puff production experimental method and device. The method is characterized by comprising the steps that 1, a core model for an experiment is vacuumized; 2, simulation formation water is sucked into the core model till the core model absorbs water to reach saturation; 3, crude oil is injected into the core model till no simulation formation water is drained out of the core model; 4, according to the solution gas-oil ratio data of a target oil field to be measured and core model output simulation formation water volume, the volume of gas needing to be injected into the core model is worked out; 5, the gas is injected into the core model; 6, huff-puff fluid is injected into the core model, the core model is closed, and a soaking process is simulated; 7, after experiment time is up, the core model is opened for huff-puff fluid and crude oil spurt, and one-time physical simulation huff-puff production experiment is completed. Experiments in different huff-pull ways can be carried out, influence effects of different injection parameters or parameter quantized comparison effect data, and a reliable evaluation platform is provided for thickened oil field exploitation in different huff-puff ways.

The invention relates to a small-diameter tubular pump pump-passing depth checking perforating and pumping combined production method. The method includes adopting a perforating and pumping combined pump and a small-diameter gamma depth checking gauge, tripping in a standing valve along with a perforating and pumping combined tubing string and a pumping-down tool to a design position, tripping in the small-diameter gamma depth checking gauge for pump-passing depth checking, adjusting the tubing string to enable a perforating gun to align to a perforating formation, tripping in a pumping rod plunger and a blanking plug, performing pump bumping and well completion, then performing annulus pressure perforating, and starting to pump and produce after perforating. By the technology, the purposes for accurate located perforating of oil sheets and pumping after perforating are achieved, oil layers are protected effectively, well control safety in construction is improved, and technical support is provided for well-killing-free production of high-pressure oil wells and high-gas-oil-ratio oil wells.

The invention discloses a method for increasing condensate oil recovery ratios of condensate gas reservoirs by means of gas injection vertical displacement, and belongs to the technical field of condensate gas field development. The method includes selecting proper injected gas according to a principle that a gravitational differentiation phenomenon is obvious when a density ratio of the preferable injected gas to fluid of the gas reservoirs is lower than 0.75 under a formation condition in gas injection physical model experiments and actual production; determining injection and production well locations, perforation intervals, well patterns and well spacing by the aid of a kinetic mechanical analysis process for micro-elements of the injected gas so as to effectively form artificial gas caps in gas injection procedures; determining critical gas production rates according to a critical production rate correction formula. The critical gas production rates are used for preventing increase of gas-oil ratios due to coning of the injected gas. The method has the advantages that the artificial gas caps can be formed at high structural positions by the injected gas, condensate gas can be subjected to vertical downward displacement by the aid of the injected gas, accordingly, the sweep efficiency of the injected gas is close to 100%, and the injected gas utilization rate and the final condensate oil recovery ratios can be obviously increased.

A method for monitoring oil based mud filtrate contamination is provided including steps of analytically dividing a fluid stream into two parts, determining a gas/oil ratio for a native fluid determining an apparent gas/oil ratio for the contaminated fluid and determining on a volume fraction, an oil based contamination level based upon the gas/oil ratio for the native fluid and the apparent gas/oil ratio for the contaminated fluid.