304 results about "Rate of penetration" patented technology

Apparatus and methods of using lasers are provided for the perforation of oil and gas well casings and rock formations. A rock removal process called laser spallation is provided that utilizes a combination of laser-induced thermal stress and laser induced superheated steam explosions just below the surface of the laser / rock interaction to spall or fracture the rock into small fragments that can then be easily removed from the rock formation. The use of high power laser beams of kilowatt level is provided to rapidly cut the steel casings and perforate into the formation. Techniques of the invention increase permeability and reduce hole tapering while perforating a deep hole in reservoir rock formations.

The invention relates to a torsional impact drilling tool used for applying low amplitude high frequency torsional impact to a drill bit during a drilling process, which can increase the drilling efficiency and the service life of the drill bit and lesson the tripping operation and the drilling cost. The technical scheme of the torsional impact drilling tool is as follows: a housing is connected with a short section of a drilling column led into the drill bit by a spline, and is positioned by a shaft shoulder; a screw motor rotor and a screw motor stator form a screw motor, the screw motor rotor is eccentrically connected to a transmission shaft by a universal shaft and two bearings, and four diversion holes are arranged on the transmission shaft; the lower end of the transmission shaft is connected with a carrier with a cavity; a sliding impactor is arranged in the cavity and is fixed by pins, and an impact hammer is arranged in the sliding impactor; a falling prevention ring is connected with the housing by screw threads; and the damping shaft shoulder on the short section of the drilling column led into the drill bit is matched with the impact hammer of the sliding impactor to form a ratchet wheel structure. The torsional impact drilling tool has simple structure, and can be used in hard strata of a deep well; and as being short, the tool is also applicable to the deflecting operation and can be used in crooked well holes, thereby reducing the phenomenon of stick-slip of the drill bit and improving the rate of penetration.

A method and apparatus for determining the fluid permeability of an earth formation is described. An instrument comprising an acoustic source and acoustic and electrokinetic sensors is located in a borehole at a site of interest. The acoustic source is fired and the resulting variations in pressure and electric field generated are measured and recorded. The Biot equation, and an equation for the streaming potential coupled to fluid displacement terms, is solved using finite element analysis to give an expected pressure waveform and electrokinetic waveform based on estimated earth formation properties. By comparison of the measured waveforms and those calculated from the equations, the actual permeability of the earth formation can be deduced.

Methods and related systems are described relating to an inversion approach for interpreting the geophysical electromagnetic data. The inversion can be constrained by using a multiphase fluid flow simulator (incorporating pressure data if available) which simulates the fluid flow process and calculates the spatial distribution of the water saturation and the salt concentration, which are in turn transformed into the formation conductivity using a resistivity-saturation formula. In this way, the inverted invasion profile is consistent with the fluid flow physics and moreover accounts for gravity segregation effects. Jointly with the pressure data, the inversion estimates a parametric one-dimensional distribution of permeability and porosity. The fluid flow volume is directly inverted from the fluid-flow-constrained inversion of the electromagnetic data. The approach is not limited by the traditional interpretation of the formation test, which is based on a single-phase model without taking into account invasion or assuming that the fluid, for example mud-filtrate, has been cleaned up from the formation testing zone. The joint inversion of the electromagnetic and pressure data provides for a more reliable interpretation of formation permeability. One advantage of the approaches described herein, is its possible generalization to three-dimensional geometries, for example dipping beds and highly deviated wells.

A method for determining formation pressure at a depth region of formations surrounding a borehole, including: keeping track of the time since cessation of drilling at the depth region; deriving formation permeability at the depth region; causing wellbore pressure to vary periodically in time and determining, at the depth region, the periodic and non-periodic component of pressure measured in the formations; determining, using the time, the periodic component and the permeability, the formation pressure diffusivity and transmissibility and an estimate of the size of the pressure build-up zone around the wellbore at the depth region; determining, using the time, the formation pressure diffusivity and transmissibility, and the non-periodic component, the leak-off rate of the mudcake at the depth region; determining, using the leak-off rate, the pressure gradient at the depth region; and extrapolating, using the pressure gradient and the size of the build-up zone, to determine the formation pressure.

A rotary drill bit with cutting elements operable to control depth of cut and rate of penetration during formation of a wellbore are provided. Respective sets of secondary cutting elements and primary cutting elements may also be disposed on exterior portions of a rotary drill bit. A number of blades may extend from exterior portions of the drill bit with a number of cutting elements disposed on exterior portions of each blade. Each cutting element may include a substrate with a cutting surface disposed thereon. A respective protector may extend from the cutting surface of one or more cutting elements to limit depth of penetration of the associated cutting element into adjacent portions of a downhole formation and / or to control rate of penetration of an associated rotary drill bit.

An integrated device for in-situ generation and decomposition of hydrate sediments and permeability measurement thereof belongs to the field of measuring the basic physical properties of natural gas hydrates. The device mainly comprises a reaction kettle, a cold store, a scavenging leakage detection system, a temperature control system, a gas supply system, a water supply system, a permeability measurement system and a computer data acquisition system. A compression type design is adopted for the reaction kettle so that different stress states can be simulated. The device has the following advantages that: the cold store and a constant temperature bath are capable of realizing quick and accurate control of temperatures; the gas supply system is quick and convenient to increase and preserve pressures; the data acquisition system has the functions of data storage and real-time analysis; the temperatures, pressures, historical sedimentary conditions and stress states of different hydratesediment reservoirs can be simulated; and a hydrate sediment sample can be integrally taken out in a relatively convenient manner, and can be directly put in a low-temperature high-pressure three-axis tester for the mechanical characteristic testing research. Besides, the device plays an important role in guiding the drilling and safe mining of natural gas hydrates.

The invention provides a method and a device for confirming the rock permeability. The method comprises the following steps: measuring a series of selected rock core samples to obtain rock permeability values; measuring transverse relaxation time T2 distribution and rock core capillary pressure curves of water-saturated rock core samples with different permeability values; confirming the relationship of the transverse relaxation time T2 distribution of the rock core samples and pore throat radius distribution of the rock core samples according to a function relationship of the transverse relaxation time T2 distribution and the rock core capillary pressure curves; uniformly dividing the transverse relaxation time T2 distribution and the pore throat radius distribution of the rock core samples into n groups; and calculating porosity components and average pore throat radiuses of the different groups of rock core samples. The rock permeability is confirmed by dividing the plurality groups of porosity components and average pore throat radius components through the nuclear magnetic resonance T2 distribution. The seepage characteristics of reservoir rocks are reflected in a relatively real manner through the permeability calculated by using the method and the device provided by the invention, the consistency with the rock core analysis permeability result is good, and the calculation result is accurate.

This invention presents various embodiments, including a system and a method, in which pressure-while-drilling data is gathered at a drilling rig and compared to modeled ECD pressure data related to the bore hole. The actual and modeled data are statistically analyzed to generate standard deviation data, which is used to infer information about how rapid a rate of penetration may safely be employed to optimize drilling results.

A method for determining formation pressure at a depth region of formations surrounding a borehole, including: keeping track of the time since cessation of drilling at the depth region; deriving formation permeability at the depth region; causing wellbore pressure to vary periodically in time and determining, at the depth region, the periodic and non-periodic component of pressure measured in the formations; determining, using the time, the periodic component and the permeability, the formation pressure diffusivity and transmissibility and an estimate of the size of the pressure build-up zone around the wellbore at the depth region; determining, using the time, the formation pressure diffusivity and transmissibility, and the non-periodic component, the leak-off rate of the mudcake at the depth region; determining, using the leak-off rate, the pressure gradient at the depth region; and extrapolating, using the pressure gradient and the size of the build-up zone, to determine the formation pressure.

A drilling fluid compound, for use as an additive in a water-based drilling mud system, comprises a neat (B100) biodiesel liquid at a concentration of at least 5% by volume, and is useful in downhole applications such as lubrication, spotting, shale inhibition, fluid loss control, and rate of penetration enhancement. A base fluid for a synthetic-based drilling mud system comprises a B100 biodiesel liquid at a concentration of at least 5% by volume. A polyalphaolefin, another isomerized olefin, a petrodiesel, a mineral oil, a mineral oil derivative, or combinations thereof, may also be included in the drilling fluid compound or in the base fluid, within suitable ranges. The compositions of matter satisfy the current environmental standards defined by the U.S. Environmental Protection Agency for drilling fluids.

The invention discloses a device for simultaneously measuring expansion and permeability rate of gas injected into a coal rock under a tri-axial stress condition. The device comprises a gas injection system (1), a confining pressure system (2), an axial pressure loading machine (25), a permeability measuring system (3) and a data acquisition system (4), wherein the gas outlet port of the gas injection system (1) is connected with the gas inlet port of the confining pressure system (2) through a high pressure gas inlet pipe (43); the axial pressure loading machine (25) is arranged at the external part of the confining pressure system (2); the permeability measuring system (3) is connected with the gas outlet port of the confining pressure system (2) through a high pressure gas pipe; and the data acquisition system (4) is connected with the confining pressure system (2) through a data line with a sensor. According to the device provided by the invention, the problem of measuring coal-body deformations and permeability variations of different adsorption gases at different temperatures and different pressures is effectively solved; in addition, the permeability and coal-body change laws caused by a gas injection displacement in the process of developing coal bed gases are effectively simulated so that the production practice is beneficial to be further guided.

A method for predicting the rate of penetration (ROP) of a drill bit drilling a well bore through intervals of rock of a subterranean formation is provided. The method uses an equation based upon specific energy principles. A relationship is determined between a bit-specific coefficient of sliding friction μ and confined compressive strength CCS over a range of confined compressive strengths CCS. Similarly, another relationship for the drill bit is determined between mechanical efficiency EFFM and confined compressive strength CCS over a range of confined compressive strengths CCS. Confined compressive strength CCS is estimated for intervals of rock through which the drill bit is to be used to drill a well bore. The rate of penetration ROP is then calculated utilizing the estimates of confined compressive strength CCS of the intervals of rock to be drilled and those determined relationships between the bit-specific coefficient of sliding friction μ and the mechanical efficiency EFFM and the confined compressive strengths CCS, as well as using estimated drill bit speeds N (RPM) and weights on bit (WOB).

The invention relates to a lower limit method for the reservoir forming physical property of an effective reservoir layer under the restraint of reservoir forming power and pore structure, comprising the following step of: on the basis of building a function relationship between the tension force of an oil-water interface and the temperature of a stratum system, building a function relationship between the semidiameter and the permeability of a maximum through hole throat of a reservoir layer, and building a function relationship between K / phi and K of the reservoir layer under the restraint of hole throat structure type, computing the reservoir forming physical property lower limit of the effective reservoir layer under the restraint of the reservoir forming power and the pore structure under different stratum temperature conditions. The research result of the method is combined with the research result of the physical property recovery and the reservoir forming power recovery of the reservoir layer in the geological historical period, so that the effectiveness of the reservoir layer in the geological historical period can be evaluated, and the oil gas distribution law in the reservoir forming period can be analyzed, therefore, the method has an important meaning for guiding the oil-gas exploration and deployment.

By removing material of low permeability from within and around a perforation tunnel and creating at least one fracture at the tip of a perforation tunnel, injection parameters and effects such as outflow rate and, in the case of multiple perforation tunnels benefiting from such cleanup, distribution of injected fluids along a wellbore are enhanced. Following detonation of a charge carrier, a second explosive event is triggered within a freshly made tunnel, thereby substantially eliminating a crushed zone and improving the geometry and quality (and length) of the tunnel. In addition, this action creates substantially debris-free tunnels and relieves the residual stress cage, resulting in perforation tunnels that are highly conducive to injection under fracturing conditions for disposal and stimulation purposes, and that promote even coverage of injected fluids across the perforated interval.

A method for predicting the rate of penetration (ROP) of a drill bit drilling a well bore through intervals of rock of a subterranean formation is provided. The method uses an equation based upon specific energy principles. A relationship is determined between a bit-specific coefficient of sliding friction μ and confined compressive strength CCS over a range of confined compressive strengths CCS. Similarly, another relationship for the drill bit is determined between mechanical efficiency EFFM and confined compressive strength CCS over a range of confined compressive strengths CCS. Confined compressive strength CCS is estimated for intervals of rock through which the drill bit is to be used to drill a well bore. The rate of penetration ROP is then calculated utilizing the estimates of confined compressive strength CCS of the intervals of rock to be drilled and those determined relationships between the bit-specific coefficient of sliding friction μ and the mechanical efficiency EFFM and the confined compressive strengths CCS, as well as using estimated drill bit speeds N (RPM) and weights on bit (WOB).

Determination of hydraulic properties such as porosity and permeability of soil is of paramount importance in hydrology and civil engineering. In order to achieve greater accuracy in determination of permeability of soil using falling head permeameter, the two important known constraints of human monitoring error in noting the falling water level between two selected levels and elapse time between these two levels had overcome through electronically sensing the levels between two selected points and activating the timer clock automatically by the pulses coming from senor. The precision in measurement of time lapse in 1 / 100th a second enables greater accuracy in estimation of permeability. Provision of perforated Teflon disc above and below the soil core facilitates in application of water uniformly over the entire surface area of soil core at top and similar way permeated water leaving the soil core uniformly without any obstruction. The use of carbon steel seamless tube while collecting soil core facilitated in undisturbed soil core recovery from desired depth section. The permeability test was conducted for various sorted sands of different size ranges and each sample was subjected to repetitive tests and elapsed time for each test was recorded from timer unit. Coefficient of Permeability was calculated for each test. The lab experiment conducted for sorted and unsorted sediments has yielded a consistent performance of Electronic level sensor and timer based falling head soil permeameter.

A method of constraining a stochastic model of Gaussian or related type, representing a porous medium such as an underground reservoir, to data characteristic of the displacement of the fluids is disclosed. The method is based on an iterative development in two stages. The first stage carries out a flow simulation, in identifying zones inside the reservoir and in estimating the modification to be brought to the effective permeabilities of these zones so as to improve calibration between the real data and the corresponding responses obtained with the flow simulator. The second stage involves an intermediate optimization problem intended to minimize an intermediate objective function (implemented from a gradual deformation technique) measuring the difference between the effective permeabilities calculated for the zones and the effective permeabilities identified during the first stage for better calibration.

An apparatus and method for determining permeability of a subterranean formation is provided. The apparatus and method comprise a work string, at least one selectively extendable member mounted on the work string to isolate a portion of the annular space between the work string and borehole. A predetermined distance proportional to the radius of a control port separates at least two ports in the work string. A sensor operatively associated with each port is mounted in the work string for measuring at least one characteristic such as pressure of the fluid in the isolated section.

The invention relates to the visual gap level plane module oil field exploration using man made authentic acidite micro module, choosing air penetration rate bigger than 0.2-0.3 mum natural or artificial acidite core, using fluid abietyl to fill the acidite core, sticking epoxide resin on the clean flat glass, grinding the core into the particle with diameter one third of the acidite granite, using the other of the same size to the core, connecting fluid injection and extraction at both ends of the core. The made module can vividly express the penetration rate of the oil reserve rock, suitable for oil and water alternating substitution, representing the actual flow of fluids of the underground fluids, with visuality for dynamic saturation quantitative analysis.

An improved oil and gas drilling control system which utilizes improved braking and feedback technology which, in turn, permits more precise weight-on-bit control and more smooth transitions of weight-on-bit than any existing technology. In addition, the system also permits more accurate feedback and control with respect to drilling depth, pipe transitions, and rate of penetration than prior systems.

Methods, systems, and tool assemblies for distributing weight between a bit and a reamer device are disclosed. For example, at least one of the drill bit and the reamer may be configured to selectively distribute a weight-on-bit between the drill bit and the reamer, such as within a predetermined range. Additionally, methods of drilling wellbores may include selectively distributing a weight-on-bit applied to a bottom hole assembly between a drill bit and a reamer of the bottom hole assembly. Also, a reamer may be configured to exhibit a first maximum rate-of-penetration into a relatively hard formation, and a drill bit may be configured to exhibit a second maximum rate-of-penetration into a relatively soft formation that is less than the first maximum rate-of-penetration.

A liquid nitrogen cyclic freeze-thaw permeability-improvement gas drainage method based on horizontal directional boreholes comprises: first constructing a main borehole at an intake roadway or a return roadway, a low-level roadway and a high-level roadway, after a drill bit reaches a pre-set target position of a coal bed, uniformly and directionally constructing a plurality of branch boreholes along a horizontal direction of the coal bed, injecting water to the coal bed, opening a valve, filling the main boreholes with liquid nitrogen, rapidly freezing the water injected into the branch boreholes and the periphery of the coal bed, and stopping injecting the nitrogen when an average temperature of a pre-permeability-improvement area monitored by a temperature measuring hole is lowered to −2° C. or lower.

This invention relates to methods for calibrating a formation permeability model with respect to data obtained from fluid flow measurements. A method according to the invention includes determining a correlation coefficient for a porosity-irreducible water saturation relationship; determining a leading coefficient for a formation permeability model; and determining at least one exponent parameter for the formation permeability model by minimizing a basis function that represents a difference between a formation permeability estimate derived from the formation permeability model and a formation permeability estimate derived from the fluid flow measurements.

A method for simulating water-hammer waves in a borehole is used to estimate formation parameters such as porosity and permeability, and to design completion strings. The simulation method uses a model that has a plurality of layers, at least one of the layers includes radial layering.

In one aspect of the invention, a downhole sensor system comprises at least one downhole sensor disposed on or within a downhole component of a tool string. The downhole sensor is adapted to detect at least one characteristic of a downhole formation adjacent the downhole component. The downhole sensor has a variable sampling rate controlled by a processing element. The processing element is in electrical communication with a tool string rate-of-penetration sensor and / or a tool string rotational speed sensor. The processing element is adapted to vary the sampling rate in response to the rate-of-penetration and / or rotational speed of the tool string. In some embodiments, the system is a closed loop system.

An earth-boring tool system that includes a drilling assembly for drilling a wellbore and a surface control unit. The surface control unit includes a prediction system that is configured to train a hybrid physics and machine-learning model based on input data, provide, via the hybrid model, a predictive model representing a rate of penetration of an earth-boring tool and wear of the earth-boring tool during a planned drilling operation, provide one or more recommendations of drilling parameters based on the predictive model, utilize the one or more recommendations in a drilling operation, receive real-time data from the drilling operation, retrain the hybrid model based on a combination of the input data and the real-time data, and provide, via the retrained model, an updated predictive model of a rate of penetration of an earth-boring tool and wear of the earth-boring tool during a remainder of the planned drilling operation.