The disclosure describes a BHA that generates electricity downhole which can then be utilized with an electric motor to turn the drive shaft and for drive shaft orientation. The disclosure also describes a more accurate MWD measurements by placing MWD sensors closer to drill bit.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Method of decomposing high molecular weight polymer downhole to prevent chelation of iron by residual high molecular weight polymer thereby producing flowback without iron contamination as chelated iron. A secondary method is also described to treat iron chelated produced water with oxidants at surface conditions, utilizing aluminum electrolytes, specifically low basicity polyaluminum chloride, to either co-precipitate residual polymer and bound iron, or to substitute chelated iron with aluminum in the polymer-metal complex, resulting in liberating of iron to enable neutral pH oxidation and removal by precipitation, coagulation, flocculation and physical separation. The produced water with removed iron can be then stored or re-used for other oilfield applications.
The disclosure describes a BHA that generates electricity downhole. The generated electricity can then be utilized with an electric motor to turn the drive shaft and for drive shaft orientation. The disclosure also describes a more accurate MWD measurements by placing MWD sensors closer to drill bit.
Method of decomposing high molecular weight polymer downhole to prevent chelation of iron by residual high molecular weight polymer thereby producing flowback without iron contamination as chelated iron. A secondary method is also described to treat iron chelated produced water with oxidants at surface conditions, utilizing aluminum electrolytes, specifically low basicity polyaluminum chloride, to either co-precipitate residual polymer and bound iron, or to substitute chelated iron with aluminum in the polymer-metal complex, resulting in liberating of iron to enable neutral pH oxidation and removal by precipitation, coagulation, flocculation and physical separation. The produced water with removed iron can be then stored or re-used for other oilfield applications.
The invention relates to a cementing tool for use in oil and gas well decommissioning operations, in particular so called perforate, wash and cement procedures. The tool (1) is designed for running in a well on drill string and for jetting cement through previously formed perforations in the casing (10) to fill the outer annulus (9) with cement. The tool (1) has a cylindrical wall (3) which is formed from steel (11) and elastomeric (5) elements, whereby it is expandable between a first diameter in which it may be run down the well and a second, larger diameter deployed during cementing operations. (FIG. 2).
An embodiment of a method for supplying refrigerants to a liquefied natural gas (LNG) facility includes: advancing a first refrigerant from a first storage device to a heat exchanger, the first refrigerant having a first temperature; advancing a second refrigerant from a second storage device to the heat exchanger, the second refrigerant having a second temperature different than the first temperature; flowing the first refrigerant and the second refrigerant through the heat exchanger; adjusting the second temperature based on at least a transfer of heat between the first refrigerant and the second refrigerant in the heat exchanger; and transferring the first refrigerant and the second refrigerant to the LNG facility.
F25B 45/00 - Arrangements for charging or discharging refrigerant
F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen
The present disclosure generally relates to harvesting geothermal energy from mature and near end-of-life oil and gas reservoirs that have been subjected to secondary oil recovery steam processes like steam-assisted gravity drainage (SAGD), steamflood, etc. The geothermal potential of these mature SAGD reservoirs can be used to generate green electricity thus reducing the greenhouse gas (GHG) footprint of the oil production. Lateral spacing of injectors and producers, with closing of unused members of a well-pair for energy recovery is described.
F24T 10/30 - Geothermal collectors using underground reservoirs for accumulating working fluids or intermediate fluids
F24T 10/20 - Geothermal collectors using working fluid injected directly into the ground, e.g. using injection wells and recovery wells
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
Method of cleaning sucker rods using a portable cleaning tool containing a rotating brush assembly to remove scale and corrosion residue on the sucker rods is described herein. The brush is annular with an empty or hollow center, such that the rod can penetrate through the hole in the brush. The tool is powered by air compression, and also contains a mechanism of removing the collected debris for disposal. The cleaning tool assembly could be either a standalone device on site placed on a mounted rack, or could be attached to the rod to be cleaned.
A46B 13/02 - Brushes with driven brush bodies power-driven
A46D 1/00 - Bristles; Selection of materials for bristles
B08B 13/00 - Accessories or details of general applicability for machines or apparatus for cleaning
B08B 15/04 - Preventing escape of dirt or fumes from the area where they are produced; Collecting or removing dirt or fumes from that area from a small area, e.g. a tool
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
9.
SYSTEM AND METHOD FOR TURNING WELL OVER TO PRODUCTION
A system and method for turning a well over to production. The method may include drilling a wellbore using a drillstring, casing the wellbore, fracturing a reservoir, drilling the wellbore to a plug back total depth using the drillstring to clean out the wellbore, and converting the drillstring from a drilling mode to a production mode.
The present disclosure generally relates to harvesting geothermal energy from mature and near end-of-life oil and gas reservoirs that have been subjected to secondary oil recovery steam processes like steam-assisted gravity drainage (SAGD), steamflood, etc. The geothermal potential of these mature SAGD reservoirs can be used to generate green electricity thus reducing the greenhouse gas (GHG) footprint of the oil production. Lateral spacing of injectors and producers, with closing of unused members of a well-pair for energy recovery is described.
Method of cleaning sucker rods using a portable cleaning tool containing a rotating brush assembly to remove scale and corrosion residue on the sucker rods is described herein. The brush is annular with an empty or hollow center, such that the rod can penetrate through the hole in the brush. The tool is powered by air compression, and also contains a mechanism of removing the collected debris for disposal. The cleaning tool assembly could be either a standalone device on site placed on a mounted rack, or could be attached to the rod to be cleaned.
A system and method for turning a well over to production. The method may include drilling a wellbore using a drillstring, casing the wellbore, fracturing a reservoir, drilling the wellbore to a plug back total depth using the drillstring to clean out the wellbore, and converting the drillstring from a drilling mode to a production mode.
Implementations described and claimed herein provide systems and methods for developing resources from a reservoir. In one implementation, obtaining nuclear magnetic resonance (NMR) log data is obtained for one or more wells of the reservoir. The NMR data is captured using one or more logging tools. An interpreted NMR log is generated by quantifying one or more fluid producibility parameters. The one or more fluid producibility parameters are quantified by processing the NMR log data using automated unsupervised machine learning. A production characterization of the reservoir is generated based on the interpreted NMR log, with the reservoir being developed based on the production characterization.
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
G01R 33/50 - NMR imaging systems based on the determination of relaxation times
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
14.
INTEGRATED RESERVOIR CHARACTERIZATION USING NMR T1-T2 MEASUREMENTS
Implementations described and claimed herein provide systems and methods for developing resources from a reservoir. In one implementation, obtaining nuclear magnetic resonance (NMR) log data is obtained for one or more wells of the reservoir. The NMR data is captured using one or more logging tools. An interpreted NMR log is generated by quantifying one or more fluid producibility parameters. The one or more fluid producibility parameters are quantified by processing the NMR log data using automated unsupervised machine learning. A production characterization of the reservoir is generated based on the interpreted NMR log, with the reservoir being developed based on the production characterization.
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
G01R 33/50 - NMR imaging systems based on the determination of relaxation times
Systems and methods for reservoir modeling include a super resolution seismic data conversion platform for converting input seismic data into high resolution output seismic data. The super resolution seismic data conversion platform can perform a super resolution inversion on the input seismic data by imposing sparsity and/or coherency assumptions on geophysical parameters represented by wavelet information of the input seismic data. For instance, a seismic trace interval can be determined, and both a reflection coefficient and an acoustic impedance of the seismic trace interval can be constrained. An optimization problem, using the constrained reflection coefficient and the constrained acoustic impedance, can be generated and/or solved by a sparse inversion. As such, a vertical resolution, as well as a seismic bandwidth, of super resolution output seismic data can be increased, improving subterranean feature (e.g., sand and/or shale characteristics) interpretation and well planning and construction.
Systems and methods for reservoir modeling include a super resolution seismic data conversion platform for converting input seismic data into high resolution output seismic data. The super resolution seismic data conversion platform can perform a super resolution inversion on the input seismic data by imposing sparsity and/or coherency assumptions on geophysical parameters represented by wavelet information of the input seismic data. For instance, a seismic trace interval can be determined, and both a reflection coefficient and an acoustic impedance of the seismic trace interval can be constrained. An optimization problem, using the constrained reflection coefficient and the constrained acoustic impedance, can be generated and/or solved by a sparse inversion. As such, a vertical resolution, as well as a seismic bandwidth, of super resolution output seismic data can be increased, improving subterranean feature (e.g., sand and/or shale characteristics) interpretation and well planning and construction.
04 - Industrial oils and greases; lubricants; fuels
35 - Advertising and business services
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Crude oil, condensate, natural gas liquids, natural gas,
liquefied natural gas, hydrocarbon gases, and liquefied
petroleum gas. Providing business information in the field of the oil and
gas industries, and in the field of the renewal energy
business. Production of crude oil, nature gas, petroleum, petroleum
condensate, natural gas liquids, and hydrocarbon fuels in
solid, liquid or gaseous form; oil and gas industry
services, namely, production and processing of hydrocarbons;
oil processing services, namely, oil refining; operation of
wells, namely, oil and gas well treatment; production of
renewal energy. Exploration of crude oil, natural gas, petroleum and
petroleum condensate; technical consultation and research
services in the field of exploration, processing and
production of crude oil, natural gas, petroleum, and
petroleum condensate; technical consultation and research
services in the field renewable energy.
04 - Industrial oils and greases; lubricants; fuels
35 - Advertising and business services
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Crude oil, condensate, natural gas liquids, natural gas,
liquefied natural gas, hydrocarbon gases, and liquefied
petroleum gas. Providing business information in the field of the oil and
gas industries, and in the field of the renewal energy
business. Production of crude oil, nature gas, petroleum, petroleum
condensate, natural gas liquids, and hydrocarbon fuels in
solid, liquid or gaseous form; oil and gas industry
services, namely, production and processing of hydrocarbons;
oil processing services, namely, oil refining; operation of
wells, namely, oil and gas well treatment; production of
renewal energy. Exploration of crude oil, natural gas, petroleum and
petroleum condensate; technical consultation and research
services in the field of exploration, processing and
production of crude oil, natural gas, petroleum, and
petroleum condensate; technical consultation and research
services in the field renewable energy.
20.
SYSTEMS AND METHODS FOR ISOLATION DETECTION USING A SYMMETRY INVARIANT LOG
Aspects of the present disclosure relate generally to analyzing subterranean cylindrical structures using acoustic sensing. On example includes: sending first acoustic waves in the wellbore via a radial acoustic sensor; receiving first reflection waves associated with the first acoustic waves via the radial acoustic sensor; sending second acoustic waves in the wellbore via the radial acoustic sensor; receiving second reflection waves associated with the second acoustic waves via the radial acoustic sensor; processing recorded data associated with the first acoustic waves, the first reflection waves, the second acoustic waves, and the second reflection waves, wherein the first acoustic waves are associated with a first radial direction, and wherein the second acoustic waves are associated with a second radial direction, the second radial direction being opposite the first radial direction; and generating a plot for identification of one or more isolation regions in the wellbore based on the processing.
E21B 47/0224 - Determining slope or direction of the borehole, e.g. using geomagnetism using seismic or acoustic means
E21B 47/085 - Measuring diameters or related dimensions at the borehole using radiant means, e.g. acoustic, radioactive or electromagnetic
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
Aspects of the present disclosure relate generally to analyzing subterranean cylindrical structures using acoustic sensing. On example includes: sending first acoustic waves in the wellbore via a radial acoustic sensor; receiving first reflection waves associated with the first acoustic waves via the radial acoustic sensor; sending second acoustic waves in the wellbore via the radial acoustic sensor; receiving second reflection waves associated with the second acoustic waves via the radial acoustic sensor; processing recorded data associated with the first acoustic waves, the first reflection waves, the second acoustic waves, and the second reflection waves, wherein the first acoustic waves are associated with a first radial direction, and wherein the second acoustic waves are associated with a second radial direction, the second radial direction being opposite the first radial direction; and generating a plot for identification of one or more isolation regions in the wellbore based on the processing.
Implementations described and claimed herein provide systems and methods for increasing production performance in a Steam Assisted Gravity Drainage system. In one implementation, an upper mating unit of an inverted shroud assembly is received with a lower mating unit of the inverted should assembly in a slidable relationship. The upper mating unit is coupled to a pump-intake assembly. The lower mating unit is coupled to a motor-seal assembly. The slidable relationship secures the pump-intake assembly to the motor-seal assembly. A motor of the motor-seal assembly is directly cooled by opening the motor to a production well based on an exterior attachment of the motor-seal assembly relative to an inverted shroud.
04 - Industrial oils and greases; lubricants; fuels
35 - Advertising and business services
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Crude oil, condensate, natural gas liquids, natural gas, liquefied natural gas, hydrocarbon gases, and liquefied petroleum gas. Providing business information in the field of the oil and gas industries, and in the field of the renewal energy business. Production of crude oil, natural gas, petroleum, petroleum condensate, natural gas liquids, and hydrocarbon fuels in solid, liquid or gaseous form; oil and gas industry services, namely production and processing of hydrocarbons; oil processing services, namely, oil refining; operation of wells, namely oil and gas well treatment; production of renewal energy. Exploration of crude oil, natural gas, petroleum and petroleum condensate; technical consultation and research services in the field of exploration, processing and production of crude oil, natural gas, petroleum, and petroleum condensate; technical consultation and research services in the field renewable energy.
04 - Industrial oils and greases; lubricants; fuels
35 - Advertising and business services
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Crude oil, condensate, natural gas liquids, natural gas, liquefied natural gas, hydrocarbon gases, and liquefied petroleum gas. Providing business information in the field of the oil and gas industries, and in the field of the renewal energy business. Production of crude oil, natural gas, petroleum, petroleum condensate, natural gas liquids, and hydrocarbon fuels in solid, liquid or gaseous form; oil and gas industry services, namely production and processing of hydrocarbons; oil processing services, namely, oil refining; operation of wells, namely oil and gas well treatment; production of renewal energy. Exploration of crude oil, natural gas, petroleum and petroleum condensate; technical consultation and research services in the field of exploration, processing and production of crude oil, natural gas, petroleum, and petroleum condensate; technical consultation and research services in the field renewable energy.
25.
CLOSED LOOP LNG PROCESS FOR A FEED GAS WITH NITROGEN
Systems and methods for processing liquefied natural gas (LNG) can include an LNG production system with a methane refrigeration cycle downstream from an ethylene refrigeration cycle. The methane refrigeration cycle can be a closed loop methane refrigeration cycle that maintains a methane refrigerant separate from a natural gas feed, (e.g., compared to an open loop methane refrigeration cycle that extracts the methane refrigerant from the natural gas feed and recombines the methane refrigerant with the natural gas feed). The natural gas feed can be a medium or high nitrogen gas feed having a nitrogen content greater than 1.0% molarity.
Implementations described and claimed herein provide systems and methods for a scripting technique to clone equation-oriented models of a modeled system for parallel simulation of the modeled system. The multiple equation-oriented models may be solved in parallel to quickly create an optimized solution for different operating conditions by providing different input variable sets to the cloned equation-oriented models. The multiple equation-oriented models may provide real-time optimization of the modeled system to provide continuous optimization of all controls or handles of the system to help achieve a target performance of the system. The equation-oriented models may also provide a nomination tool to predict the output of the system over a nomination period with different input variables and performance monitoring capabilities of the system. Offline “what-if” simulations may also be executed on the equation-oriented modeling system to aid operators in predicting performance of the modeled system and troubleshoot potential problems.
G05B 13/04 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric involving the use of models or simulators
Systems and methods for processing liquefied natural gas (LNG) can include an LNG production system with a methane refrigeration cycle downstream from an ethylene refrigeration cycle. The methane refrigeration cycle can be a closed loop methane refrigeration cycle that maintains a methane refrigerant separate from a natural gas feed, (e.g., compared to an open loop methane refrigeration cycle that extracts the methane refrigerant from the natural gas feed and recombines the methane refrigerant with the natural gas feed). The natural gas feed can be a medium or high nitrogen gas feed having a nitrogen content greater than 1.0% molarity.
Implementations described and claimed herein provide systems and methods for a scripting technique to clone equation-oriented models of a modeled system for parallel simulation of the modeled system. The multiple equation-oriented models may be solved in parallel to quickly create an optimized solution for different operating conditions by providing different input variable sets to the cloned equation-oriented models. The multiple equation-oriented models may provide real-time optimization of the modeled system to provide continuous optimization of all controls or handles of the system to help achieve a target performance of the system. The equation-oriented models may also provide a nomination tool to predict the output of the system over a nomination period with different input variables and performance monitoring capabilities of the system. Offline "what-if" simulations may also be executed on the equation-oriented modeling system to aid operators in predicting performance of the modeled system and troubleshoot potential problems.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
04 - Industrial oils and greases; lubricants; fuels
35 - Advertising and business services
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Crude oil, condensate, natural gas liquids, natural gas, liquefied natural gas, hydrocarbon gases, and liquefied petroleum gas. (1) Providing business information in the field of the oil and gas industries, and in the field of the renewal energy business.
(2) Production of crude oil, nature gas, petroleum, petroleum condensate, natural gas liquids, and hydrocarbon fuels in solid, liquid or gaseous form; oil and gas industry services, namely, production and processing of hydrocarbons; oil processing services, namely, oil refining; operation of wells, namely, oil and gas well treatment; production of renewal energy.
(3) Exploration of crude oil, natural gas, petroleum and petroleum condensate; technical consultation and research services in the field of exploration, processing and production of crude oil, natural gas, petroleum, and petroleum condensate; technical consultation and research services in the field renewable energy.
04 - Industrial oils and greases; lubricants; fuels
35 - Advertising and business services
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Crude oil, condensate, natural gas liquids, natural gas, liquefied natural gas, hydrocarbon gases, and liquefied petroleum gas. (1) Providing business information in the field of the oil and gas industries, and in the field of the renewal energy business.
(2) Production of crude oil, nature gas, petroleum, petroleum condensate, natural gas liquids, and hydrocarbon fuels in solid, liquid or gaseous form; oil and gas industry services, namely, production and processing of hydrocarbons; oil processing services, namely, oil refining; operation of wells, namely, oil and gas well treatment; production of renewal energy.
(3) Exploration of crude oil, natural gas, petroleum and petroleum condensate; technical consultation and research services in the field of exploration, processing and production of crude oil, natural gas, petroleum, and petroleum condensate; technical consultation and research services in the field renewable energy.
32.
INTEGRATED DEVELOPMENT OPTIMIZATION PLATFORM FOR WELL SEQUENCING AND UNCONVENTIONAL RESERVOIR MANAGEMENT
Implementations described and claimed herein provide systems and methods for an integrated development optimization platform for well sequencing and unconventional reservoir management. The platform integrates key elements of unconventional development planning, such as production forecast, lease obligations, surface facilities, and economics and provides analysis and data associated with past and future field development and production. In addition, development optimization platform includes the parent-child relationship as one of the determining factors of production performance, which can provide valuable insights into the frac-hit impact and infill performance. The defensive re-fracs may also be incorporated to provide a more holistic view on project investment and field development. The development optimization platform is not only an optimization platform for well sequence and development planning, but also a reservoir management tool.
G06Q 10/0631 - Resource planning, allocation, distributing or scheduling for enterprises or organisations
G06Q 10/0637 - Strategic management or analysis, e.g. setting a goal or target of an organisation; Planning actions based on goals; Analysis or evaluation of effectiveness of goals
33.
TEMPORARY SUSPENSION OF COMPLETED HYDROCARBON WELLS
In the process of suspending a subsea hydrocarbon well (1) after finalizing the completion operation and prior to stimulation of the well and putting the well on production, preinstalled upper and lower glass plugs (11, 12) are used as temporary barriers in the tubing. The plugs allow various tests to be performed before the lower plug (12), below the production packer (10), is broken; the upper plug (11) located above the downhold safety valve (13) then forms one of the barriers required to suspend the well whilst the Blow Out Preventer (BOP) is removed and Xmas tree installed, at which point the upper plug (11) is broken.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
Implementations described and claimed herein provide systems and methods for an integrated development optimization platform for well sequencing and unconventional reservoir management. The platform integrates key elements of unconventional development planning, such as production forecast, lease obligations, surface facilities, and economics and provides analysis and data associated with past and future field development and production. In addition, development optimization platform includes the parent-child relationship as one of the determining factors of production performance, which can provide valuable insights into the frac-hit impact and infill performance. The defensive re-fracs may also be incorporated to provide a more holistic view on project investment and field development. The development optimization platform is not only an optimization platform for well sequence and development planning, but also a reservoir management tool.
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G06F 30/20 - Design optimisation, verification or simulation
Implementations described and claimed herein provide apparatus and techniques for providing a seal for a polished rod. One example apparatus is a stuffing box. The stuffing box generally includes: a first flange configured to surround a polished rod; a second flange configured to surround the polished rod; a seal package disposed between the first flange and the second flang, the seal package being configured to surround and connect to the polished rod; and a flexible membrane surrounding the seal package, the flexible membrane being connected to at least a portion of the seal package.
In the process of suspending a subsea hydrocarbon well (1) after finalizing the completion operation and prior to stimulation of the well and putting the well on production, preinstalled upper and lower glass plugs (11, 12) are used as temporary barriers in the tubing. The plugs allow various tests to be performed before the lower plug (12), below the production packer (10), is broken; the upper plug (11) located above the downhole safety valve (13) then forms one of the barriers required to suspend the well whilst the Blow Out Preventer (BOP) is removed and Xmas tree installed, at which point the upper plug (11) is broken.
Implementations described and claimed herein provide apparatus and techniques for providing a seal for a polished rod. One example apparatus is a stuffing box. The stuffing box generally includes: a first flange configured to surround a polished rod; a second flange configured to surround the polished rod; a seal package disposed between the first flange and the second flang, the seal package being configured to surround and connect to the polished rod; and a flexible membrane surrounding the seal package, the flexible membrane being connected to at least a portion of the seal package.
The invention relates to a method of conducting a perf wash cement (“P/W/C”) abandonment job in an offshore oil or gas well annulus, in particular the washing or cementing operation using a rotating head with nozzles dispensing wash fluid or cement at pressure. A new design of bottom hole assembly is proposed in which the cementing tool has a relatively large diameter in order to optimize pressure whilst the wash tool has a relatively small diameter. The wash process, for a number of reasons, appears to be less sensitive to tool diameter and making the wash tool smaller reduces the overall risk of stuck pipe.
Methods for using shut-in pressures to determine uncertainties in a hydraulic fracturing process in a shale reservoir are described. Data commonly collected during multistage fracturing is used to calculate propped fracture height and induced stresses, as well as other variables, in the presence of horizontal stress anisotropy. These variables can then be incorporated into reservoir simulations to improve the fracturing monitoring, forecast hydrocarbon recoveries, or modify fracturing plans.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
E21B 41/00 - Equipment or details not covered by groups
G06F 40/143 - Markup, e.g. Standard Generalized Markup Language [SGML] or Document Type Definition [DTD]
G06F 40/117 - Tagging; Marking up ; Designating a block; Setting of attributes
H04L 9/32 - Arrangements for secret or secure communications; Network security protocols including means for verifying the identity or authority of a user of the system
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
The invention relates to various nonlimiting embodiments that include methods, apparatuses or systems for processing natural gas comprising a heavies removal column processing natural gas and light oil reflux. The overhead stream goes to heavies treated natural gas storage. The heavies removal column reboiler bottoms stream product is input to a debutanizer column. The debutanizer column overhead lights are input to a flash drum where the bottoms is pumped through a heat exchanger as a light oil reflux input to the heavies removal column, while the debutanizer reboiler bottoms product is stored as stabilized condensate. Alternatively, debutanizer column overhead lights are sent to heavies treated gas storage and the bottoms stream product goes to a depentanizer column, the overhead lights are pumped through a heat exchanger as a light oil reflux input to the heavies removal column, while the depentanizer reboiler bottoms product is stabilized condensate.
Robust methods for quantitating the amount of elemental sulfur in a fluid whereby a caustic solution is mixed with the fluid, and the elemental sulfur present in the fluid reacts to form a colored solution that can be compared to a series of standards. The methods can be performed in a laboratory or the field and allow for real time feedback. Once the concentration of the elemental sulfur is known, appropriate methods of treatment can proceed. Test kits for performing the methods in the field are also described.
A method of fracturing a reservoir wherein the main fracture stimulation treatment is preceded by depositing non dissolving solids into fracture tips where excessive downward or upward fracture growth is not desired, thereby controlling fracture geometry. The method thereby increases production of a fluid, such as water, oil or gas, from said reservoir, and avoids fracture propagation out of the pay-zone into undesirable zones.
A method of optimizing production of a hydrocarbon-containing reservoir by measuring low-frequency Distributed Acoustic Sensing (LFDAS) data in the well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow and simultaneously measuring Distributed Temperature Sensing (DTS) data from the well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow. An initial model of reservoir flow is provided using the LFDAS and DTS data; the LFDAS and DTS data inverted using Markov chain Monte Carlo method to provide an optimized reservoir model, and that optimized profile utilized to manage hydrocarbon production from the well and other asset wells.
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
G01F 1/661 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters using light
G01K 1/02 - Means for indicating or recording specially adapted for thermometers
A method of fracturing a reservoir wherein the main fracture stimulation treatment is preceded by depositing non dissolving solids into fracture tips where excessive downward or upward fracture growth is not desired, thereby controlling fracture geometry. The method thereby increases production of a fluid, such as water, oil or gas, from said reservoir, and avoids fracture propagation out of the pay-zone into undesirable zones.
The invention relates to a method and apparatus for testing a lifeboat sprinkler system without launching the lifeboat. A tank (5) of freshwater is arranged adjacent the lifeboat (1) on a marine vessel or oil platform (2). A line (24) is connected from the tank (5) to the sprinkler system of the lifeboat (1). The pressure of the water supply is arranged by means of the location of the tank (5) and/or a regulating valve (23) to mimic the pressure of the seawater that the system would access from an inlet (14) in the lifeboat hull (15) if it were launched.
B63C 9/02 - Lifeboats, life-rafts or the like, specially adapted for life-saving
A62C 37/50 - Testing or indicating devices for determining the state of readiness of the equipment
B63B 79/30 - Monitoring properties or operating parameters of vessels in operation for diagnosing, testing or predicting the integrity or performance of vessels
The invention relates to a method and apparatus for testing a lifeboat sprinkler system without launching the lifeboat. A tank (5) of freshwater is arranged adjacent the lifeboat (1) on a marine vessel or oil platform (2). A line (24) is connected from the tank (5) to the sprinkler system of the lifeboat (1). The pressure of the water supply is arranged by means of the location of the tank (5) and/or a regulating valve (23) to mimic the pressure of the seawater that the system would access from an inlet (14) in the lifeboat hull (15) if it were launched.
A62C 37/50 - Testing or indicating devices for determining the state of readiness of the equipment
A62C 3/10 - Fire prevention, containment or extinguishing specially adapted for particular objects or places in vehicles, e.g. in road vehicles in ships
Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a solvent is injected into a feed of natural gas at a solvent injection point. A mixed feed is produced from a dispersal of the solvent into the feed of natural gas. The mixed feed contains heavy components. A chilled feed is produced by chilling the mixed feed. The chilled feed includes a vapor and a condensed liquid. The condensed liquid contains a fouling portion of the heavy components condensed by the solvent during chilling. The liquid containing the fouling portion of the heavy components is separated from the vapor. The vapor is directed into a feed chiller heat exchanger following separation of the liquid containing the fouling portion of the heavy components from the vapor, such that the vapor being directed into feed chiller heat exchanger is free of freezing components.
F25J 3/02 - Processes or apparatus for separating the constituents of gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
Method of making and using a proppant from captured carbon in either a carbon mineralization process or in a carbon nanomaterial manufacturing process is discussed, followed by treatments to ensure the quality control of the proppants so that they are suitable for use in hydraulic and other reservoir fracturing methods.
Systems and methods for reservoir modeling use reservoir simulation and production data to predict future production for one or more wells. The system receives static data of a reservoir or well, receives dynamic data of the reservoir or well, and processes the static data and the dynamic data to generate a reservoir model. For instance, the static data and dynamic data can be used to generate a Voronoi grid, which is used to create a spatio-temporal dataset representing time steps for a focal well and offset wells. The reservoir model can predict reservoir performance, field development, production metrics, and operation metrics. By using one or more Machine Learning (ML) models, the systems disclosed herein can determined reservoir physics in minutes and replicate the physical properties calculated by more complex and computationally intensive reservoir modeling.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
50.
SYSTEMS AND METHODS FOR NUCLEAR MAGNETIC RESONANCE (NMR) WELL LOGGING)
Systems and method for nuclear magnetic resonance (NMR) well logging use an inversion pulse sequence with a Carr-Purcell-Meiboom-Gill (CPMG) pulse sequence to improve spin magnetization calculations. Improved Bloch equation-based calculations consider conditions where a longitudinal relaxation time and a transverse relaxation time of the hydrogen nuclei (e.g., of a subterranean hydrocarbon pool and/or water) are within an order of magnitude of pulse durations for the inversion pulse sequence and the CPMG pulse sequence. Accordingly, an NMR response to the inversion pulse sequence and the CPMG pulse can be detected and used to calculate one or more spin magnetization values with higher accuracy amplitudes. Reservoir characteristics are determined based on the one or more spin magnetization values. As such, improved well operations (e.g., selecting a drilling site, determining a drilling depth, and the like) can be performed.
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
51.
OPTIMIZING WELL SEQUENCES IN A WELL DEVELOPMENT ZONE
A computer-implemented method for optimizing a well development sequence for a development zone includes receiving one or more inputs based on the development zone. The method can also include generating a well development plan based on the development zone and the one or more inputs. Additionally, the method can also include calculating an expected value based on the well development plan. A system and a non-transitory computer-readable medium are also provided.
Systems and method for nuclear magnetic resonance (NMR) well logging use an inversion pulse sequence with a Carr-Purcell-Meiboom-Gill (CPMG) pulse sequence to improve spin magnetization calculations. Improved Bloch equation-based calculations consider conditions where a longitudinal relaxation time and a transverse relaxation time of the hydrogen nuclei (e.g., of a subterranean hydrocarbon pool and/or water) are within an order of magnitude of pulse durations for the inversion pulse sequence and the CPMG pulse sequence. Accordingly, an NMR response to the inversion pulse sequence and the CPMG pulse can be detected and used to calculate one or more spin magnetization values with higher accuracy amplitudes. Reservoir characteristics are determined based on the one or more spin magnetization values. As such, improved well operations (e.g., selecting a drilling site, determining a drilling depth, and the like) can be performed.
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
G01N 24/12 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using double resonance
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01V 3/14 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electron or nuclear magnetic resonance
53.
OPTIMIZING WELL SEQUENCES IN A WELL DEVELOPMENT ZONE
A computer-implemented method for optimizing a well development sequence for a development zone includes receiving one or more inputs based on the development zone. The method can also include generating a well development plan based on the development zone and the one or more inputs. Additionally, the method can also include calculating an expected value based on the well development plan. A system and a non-transitory computer-readable medium are also provided.
Systems and methods for reservoir modeling use reservoir simulation and production data to predict future production for one or more wells. The system receives static data of a reservoir or well, receives dynamic data of the reservoir or well, and processes the static data and the dynamic data to generate a reservoir model. For instance, the static data and dynamic data can be used to generate a Voronoi grid, which is used to create a spatio-temporal dataset representing time steps for a focal well and offset wells. The reservoir model can predict reservoir performance, field development, production metrics, and operation metrics. By using one or more Machine Learning (ML) models, the systems disclosed herein can determined reservoir physics in minutes and replicate the physical properties calculated by more complex and computationally intensive reservoir modeling.
The invention relates to a method of conducting a perf wash cement (“P/W/C”) abandonment job in an offshore oil or gas well annulus (2), in particular the washing or cementing operation using a rotating head (6, 8) with nozzles (7, 9) dispensing wash fluid or cement at pressure. Certain values of parameters of a washing or cementing job have been found surprisingly to affect the quality of the job, or the degree to which they affect the quality of the job has been unexpected. These include including rotation rate of the tool, the direction of translational movement of the tool, and the volume flow rate and pressure per nozzle of cement or wash fluid (and hence nozzle size).
Scavenging chemicals used in mitigation treatments of hydrogen sulfide in hydrocarbon streams often continue to react and form polymers that foul the processing system. Disclosed herein are methods for determining if a scavenging chemical mitigator, or its reaction or degradation product, will polymerized during or after mitigation treatments. This information allows for the optimization of mitigation treatments that pre-emptively control or prevent polymer formation. Such pre-emption measures reduce the cost and time related to remedial actions to treat polymer-fouled equipment.
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C10G 29/28 - Organic compounds not containing metal atoms containing sulfur as the only hetero atom, e.g. mercaptans, or sulfur and oxygen as the only hetero atoms
Methods and systems for liquefying natural gas using environmentally-friendly low combustibility refrigerants are provided. Methods of liquefaction include cooling a fluid in an LNG facility via indirect heat exchange with an environmentally-friendly low combustibility refrigerants that are propane, ethane and methane mixed with small amounts of fluorinated olefin, but still within close proximity to the boiling points of the pure refrigerants such that the mixed refrigerants can still be used in an optimized cascade process.
F25J 1/00 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
C09K 5/04 - Materials undergoing a change of physical state when used the change of state being from liquid to vapour or vice-versa
F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen
58.
STANDALONE HIGH-PRESSURE HEAVIES REMOVAL UNIT FOR LNG PROCESSING
Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a dry feed gas is received. The dry feed gas is chilled with clean vapor from a heavies removal column to form a chilled feed gas. The chilled feed gas is partially condensed into a vapor phase and a liquid phase. The liquid phase retains freezing components. The freezing components are extracted using a reflux stream in the heavies removal column. The freezing components are removed as a condensate. The vapor phase is compressed into a clean feed gas. The clean feed gas is free of the freezing components for downstream liquefaction.
F25J 1/00 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen
F25J 3/02 - Processes or apparatus for separating the constituents of gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
222S is captured via caustic cyanide solution and quantified by analytical methods and correspond to the concentration of elemental sulfur or amorphous dithiazine. The method has particular applicability to determine where best to drill and avoid locations of high sulfur.
The disclosure describes a method to indirectly measure the amount of elemental sulfur or amorphous dithiazine in a reservoir sample by converting them to H2S gas. The H2S is captured via caustic cyanide solution and quantified by analytical methods and correspond to the concentration of elemental sulfur or amorphous dithiazine. The method has particular applicability to determine where best to drill and avoid locations of high sulfur.
A downhole tubing rotator that has a housing configured into a production tubing string in a well in a reservoir, the housing being generally cylindrical with a hollow center and containing a two pole, three phase induction squirrel cage motor operatively connected to a tubing rotator configured to clamp onto a production tubing joint and rotate one or more production tubing joints (but not an entire production tubing string) when the motor is activated. An armor-protected insulated power and control cable connects the motor to a control box positioned at a surface of a reservoir and various sensors provide feedback for the unit. Methods of using this tool are also provided.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
04 - Industrial oils and greases; lubricants; fuels
40 - Treatment of materials; recycling, air and water treatment,
35 - Advertising and business services
42 - Scientific, technological and industrial services, research and design
Goods & Services
Crude oil, condensate in the nature of hydrocarbon fuels, natural gas liquids in the nature of liquefied natural gas, natural gas, liquefied natural gas, hydrocarbon gases for use as fuel, and liquefied petroleum gas Production of crude oil, nature gas, petroleum, petroleum condensate, natural gas liquids in the nature of liquefied natural gas, and hydrocarbon fuels in solid, liquid and gaseous form; oil and gas industry services, namely, production and processing of hydrocarbon fuels; oil processing services, namely, oil refining; operation of wells, namely, oil and gas well treatment; production of renewable energy; technical consulting in the field of production and processing of crude oil Providing business information in the field of the oil and gas industries, and in the field of the renewal energy business Exploration of crude oil, natural gas, petroleum and petroleum condensate; analysis of samples of crude oil, natural gas, petroleum, and petroleum condensate collected from processing, production, and exploration of the aforesaid goods; technological research services in the field renewable energy resources
04 - Industrial oils and greases; lubricants; fuels
40 - Treatment of materials; recycling, air and water treatment,
35 - Advertising and business services
42 - Scientific, technological and industrial services, research and design
Goods & Services
Crude oil, condensate in the nature of hydrocarbon fuels, natural gas liquids in the nature of liquefied natural gas, natural gas, liquefied natural gas, hydrocarbon gases for use as fuel, and liquefied petroleum gas Production of crude oil, nature gas, petroleum, petroleum condensate, natural gas liquids in the nature of liquefied natural gas, and hydrocarbon fuels in solid, liquid and gaseous form; oil and gas industry services, namely, production and processing of hydrocarbon fuels; oil processing services, namely, oil refining; operation of wells, namely, oil and gas well treatment; production of renewable energy; technical consulting in the field of production and processing of crude oil Providing business information in the field of the oil and gas industries, and in the field of the renewal energy business Exploration of crude oil, natural gas, petroleum and petroleum condensate; analysis of samples of crude oil, natural gas, petroleum, and petroleum condensate collected from processing, production, and exploration of the aforesaid goods; technological research services in the field renewable energy resources
64.
MACHINE LOGIC MULTI-PHASE METERING USING DISTRIBUTED ACOUSTIC SENSING DATA
A method for predicting fluid fractions is provided. The method includes building, from pressure, temperature, a fluid speed parameter, speed of sound, and fluid fractions of a first fluid flow, a machine learning model programmed to estimate fluid fractions of a fluid flow as a function of at least one Distributed Acoustic Sensing (“DAS”) fluid flow parameter and at least one physical characteristic of the fluid flow; receiving at least one DAS fluid flow parameter and the at least one physical characteristic of a second fluid flow; and determining, using the machine learning model, fluid fractions of the second fluid flow from at least the at least one DAS fluid flow parameter for the second fluid flow and the at least one physical characteristic of the second fluid flow.
G01D 5/353 - Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
G01F 1/661 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters using light
Implementations described and claimed herein provide systems and methods for determining surfactant impact on reservoir wettability. In one implementation, a nuclear magnetic resonance T1 measurement of a sample is obtained before surfactant imbibition is applied to the sample, and a second nuclear magnetic T2 measurement of the sample is made after forced imbibition of the surfactant. Moreover, another nuclear magnetic resonance T1 measurement (e.g., omitting surfactant imbibition) can be obtained simultaneously with the nuclear magnetic resonance T2 measurement using a twin core sample. The nuclear magnetic resonance T1 measurement and the nuclear magnetic resonance T2 measurement are captured under simulated reservoir conditions. A fluid typing map is generated using the nuclear magnetic resonance T1 measurement and the nuclear magnetic resonance T2 measurement. An impact of the surfactant on fluid producibility is determined based on the fluid typing map.
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01N 13/00 - Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects
G01R 33/20 - Arrangements or instruments for measuring magnetic variables involving magnetic resonance
G01R 33/44 - Arrangements or instruments for measuring magnetic variables involving magnetic resonance using nuclear magnetic resonance [NMR]
The invention relates to the alignment of a tubing hanger (14) when installed in a subsea wellhead (11). Sensors (39a,b; 40a,b) detect when the orientation is correct and send a signal to the surface to provide positive confirmation of correct orientation, before a XMT (15) is installed on the wellhead (11) and the HP riser (31) removed, etc.
The invention relates to a method and apparatus for performing acid stimulation of a hydrocarbon well (1), especially in a multi-lateral branched well system. In the first lateral (8), after installation of the production liner (9) with ball-activated completion equipment (10), acid stimulation is performed through drill string (21) which is introduced into the well and which seals with the production liner (9) by means of a stinger (22) and polished bore receptacle (23) before introduction of acid.
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
68.
MACHINE LOGIC MULTI-PHASE METERING USING DISTRIBUTED ACOUSTIC SENSING DATA
A method for predicting fluid fractions is provided. The method includes building, from pressure, temperature, a fluid speed parameter, speed of sound, and fluid fractions of a first fluid flow, a machine learning model programmed to estimate fluid fractions of a fluid flow as a function of at least one Distributed Acoustic Sensing ("DAS") fluid flow parameter and at least one physical characteristic of the fluid flow; receiving at least one DAS fluid flow parameter and the at least one physical characteristic of a second fluid flow; and determining, using the machine learning model, fluid fractions of the second fluid flow from at least the at least one DAS fluid flow parameter for the second fluid flow and the at least one physical characteristic of the second fluid flow.
The invention relates to a method and apparatus for performing acid stimulation of a hydrocarbon well (1), especially in a multi-lateral branched well system. In the first lateral (8), after installation of the production liner (9) with ball-activated completion equipment (10), acid stimulation is performed through drill string (21) which is introduced into the well and which seals with the production liner (9) by means of a stinger (22) and polished bore receptacle (23) before introduction of acid.
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
70.
METHOD AND APPARATUS FOR ALIGNING A SUBSEA TUBING HANGER
The invention relates to the alignment of a tubing hanger (14) when installed in a subsea wellhead (11). Sensors (39a,b; 40a,b) detect when the orientation is correct and send a signal to the surface to provide positive confirmation of correct orientation, before a XMT (15) is installed on the wellhead (11) and the HP riser (31) removed, etc.
Implementations described and claimed herein provide systems and methods for determining surfactant impact on reservoir wettability. In one implementation, a nuclear magnetic resonance T1 measurement of a sample is obtained before surfactant imbibition is applied to the sample, and a second nuclear magnetic T2 measurement of the sample is made after forced imbibition of the surfactant. Moreover, another nuclear magnetic resonance T1 measurement (e.g., omitting surfactant imbibition) can be obtained simultaneously with the nuclear magnetic resonance T2 measurement using a twin core sample. The nuclear magnetic resonance T1 measurement and the nuclear magnetic resonance T2 measurement are captured under simulated reservoir conditions. A fluid typing map is generated using the nuclear magnetic resonance T1 measurement and the nuclear magnetic resonance T2 measurement. An impact of the surfactant on fluid producibility is determined based on the fluid typing map.
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
The invention relates to a method and apparatus for performing acid stimulation of a hydrocarbon well (1), especially in a multi-lateral branched well system. In the first lateral (8), after installation of the production liner (9) with ball-activated completion equipment (10), acid stimulation is performed through drill string (21) which is introduced into the well and which seals with the production liner (9) by means of a stinger (22) and polished bore receptacle (23) before introduction of acid.
Implementations described and claimed herein provide systems and methods for a framework to achieve completion optimization for waterflood field reservoirs. The proposed methodology leverages adequate data collection, preprocessing, subject matter expert knowledge-based feature engineering for geological, reservoir and completion inputs, and state-of-the-art machine-learning technologies, to indicate important production drivers, provide sensitivity analysis to quantify the impacts of the completion features, and ultimately achieve completion optimization. In this analytical framework, model-less feature ranking based on mutual information concept and model-dependent sensitivity analyses, in which a variety of machine-learning models are trained and validated, provides comprehensive multi-variant analyses that empower subject-matter experts to make a smarter decision in a timely manner.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
Implementations described and claimed herein provide systems and methods for dynamic waterflood forecast modeling utilizing deep thinking computational techniques to reduce the processing time for generating the forecast model and improving the accuracy of resulting forecasts. In one particular implementation, a dataset of a field may be restructured into the spatio-temporal framework and data driven deep neural networks may be utilized to learn the nuances of data interactions to make more accurate forecasts for each well in the field. Further, the generated model may forecast a single time segment and build the complete forecast through recursive prediction instances. The temporal component of the restructured data may include all or a portion of the production history of the field divided into spaced time intervals. The spatial component of the restructure data may include, within each epoch, a computed or estimated spatial relationships of all existing wells.
Implementations described and claimed herein provide systems and methods for a framework to achieve completion optimization for waterflood field reservoirs. The proposed methodology leverages adequate data collection, preprocessing, subject matter expert knowledge-based feature engineering for geological, reservoir and completion inputs, and state-of-the-art machine-learning technologies, to indicate important production drivers, provide sensitivity analysis to quantify the impacts of the completion features, and ultimately achieve completion optimization. In this analytical framework, model-less feature ranking based on mutual information concept and model-dependent sensitivity analyses, in which a variety of machine-learning models are trained and validated, provides comprehensive multi-variant analyses that empower subject-matter experts to make a smarter decision in a timely manner.
Systems and method for predicting production decline for a target well include generating a static model and a decline model to generate a well production profile. The static model is generated with supervised machine learning using an input data set including historical production data, and calculates an initial resource production rate for the target well. The decline model is generated with a neural network using the input data and dynamic data (e.g., an input time interval and pressure data of the target well), and calculates a plurality of resource production rates for a plurality of time intervals. The system can perform multiple recursive calculations to calculate the plurality of resource production rates, generating the well production profile. For instance, the predicted resource production rate of a first time interval is used as one of inputs for predicting the resource production rate for a second, subsequent time interval.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 99/00 - Subject matter not provided for in other groups of this subclass
Implementations described and claimed herein provide systems and methods for a data management tool for accessing various databases and data sources to collect or obtain data associated with a user of the tool or a member of an organization. The data management tool may include a user interface for receiving information or inputs from a user, such as a custodian of the data, to determine the various databases and/or systems from which user data may be available. To access the user data, the data management tool may communicate with various sources or gateways to sources, such as cloud-based data storage systems, operating system gateway programs, user hardware gateway programs, and the like. Various databases storing user data may be accessible through the systems or gateways and the data management tool may request such data in response to one or more instructions received via the user interface.
Systems and methods include a geological structure modeling tool for generating a geological facies model for a target well with decision tree-based models. The decision tree-based models use geographic facie class as a target variable and receives an input data set including well log data, core data, and geological facie class labels (e.g., generated by a subject matter expert (SME)). A predictive analytics model using the decision tree-based models generates, based on an input of target well data, the geological facies model to represent underlying geological structures at a candidate location (e.g., for drilling a well) or a section of a subsurface reservoir (e.g., for resource characterization). Vertical context data can be provided to the decision tree-based models and the input data set can be artificially boosted based on geological facies class label occurrences. A well development action is selected for the candidate location based on the geological facies model.
Systems and method for predicting production decline for a target well include generating a static model and a decline model to generate a well production profile. The static model is generated with supervised machine learning using an input data set including historical production data, and calculates an initial resource production rate for the target well. The decline model is generated with a neural network using the input data and dynamic data (e.g., an input time interval and pressure data of the target well), and calculates a plurality of resource production rates for a plurality of time intervals. The system can perform multiple recursive calculations to calculate the plurality of resource production rates, generating the well production profile. For instance, the predicted resource production rate of a first time interval is used as one of inputs for predicting the resource production rate for a second, subsequent time interval.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
Implementations described and claimed herein provide systems and methods for a data management tool for accessing various databases and data sources to collect or obtain data associated with a user of the tool or a member of an organization. The data management tool may include a user interface for receiving information or inputs from a user, such as a custodian of the data, to determine the various databases and/or systems from which user data may be available. To access the user data, the data management tool may communicate with various sources or gateways to sources, such as cloud-based data storage systems, operating system gateway programs, user hardware gateway programs, and the like. Various databases storing user data may be accessible through the systems or gateways and the data management tool may request such data in response to one or more instructions received via the user interface.
A method for producing heavy oil, the method including testing a plurality of samples either from a reservoir play or simulating a reservoir play in a temperature and pressure controlled gravity drainage experiment. Test injection fluids are injected into the samples at a reservoir temperature and pressure and Cumulative Oil Production (COP) or Recovery Factor (RF) or similar feature measured over time. An injection profile is obtained by selecting n injection fluids based on a best COP or RF at a given time Tn, wherein n is a number of fluid injection stages and switching to an n+1 injection fluid when a rate of change (ROC) in the COP or RF drops at least 25%-75%, but preferably 40-60% or 50%. The injection profile is then implemented in the reservoir to produce heavy oil. Optimized injection profiles for certain reservoirs are also provided.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
Methods for preventing elemental sulfur deposition from a hydrocarbon fluid is disclosed. A mercaptan is added to a hydrocarbon fluid that has elemental sulfur and reacted with the elemental sulfur to produce a disulfide and hydrogen sulfide. Amines and/or surfactants can assist with the process. Secondary reactions between the disulfide and the elemental sulfur result in a polysulfide and a solvated sulfur-disulfide complex. The disulfide, hydrogen sulfide, polysulfide and solvated sulfur-disulfide complex do not deposit, and can optionally be removed.
C10G 29/28 - Organic compounds not containing metal atoms containing sulfur as the only hetero atom, e.g. mercaptans, or sulfur and oxygen as the only hetero atoms
Systems and methods include a geological structure modeling tool for generating a geological facies model for a target well with decision tree-based models. The decision tree-based models use geographic facie class as a target variable and receives an input data set including well log data, core data, and geological facie class labels (e.g., generated by a subject matter expert (SME)). A predictive analytics model using the decision tree-based models generates, based on an input of target well data, the geological facies model to represent underlying geological structures at a candidate location (e.g., for drilling a well) or a section of a subsurface reservoir (e.g., for resource characterization). Vertical context data can be provided to the decision tree-based models and the input data set can be artificially boosted based on geological facies class label occurrences. A well development action is selected for the candidate location based on the geological facies model.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
84.
SYSTEMS AND METHODS FOR MODELING OF DYNAMIC WATERFLOOD WELL PROPERTIES
Implementations described and claimed herein provide systems and methods for dynamic waterflood forecast modeling utilizing deep thinking computational techniques to reduce the processing time for generating the forecast model and improving the accuracy of resulting forecasts. In one particular implementation, a dataset of a field may be restructured into the spatio-temporal framework and data driven deep neural networks may be utilized to learn the nuances of data interactions to make more accurate forecasts for each well in the field. Further, the generated model may forecast a single time segment and build the complete forecast through recursive prediction instances. The temporal component of the restructured data may include all or a portion of the production history of the field divided into spaced time intervals. The spatial component of the restructure data may include, within each epoch, a computed or estimated spatial relationships of all existing wells.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
A downhole tubing rotator that has a housing configured into a production tubing string in a well in a reservoir, the housing being generally cylindrical with a hollow center and containing a two pole, three phase induction squirrel cage motor operatively connected to a tubing rotator configured to clamp onto a production tubing joint and rotate one or more production tubing joints (but not an entire production tubing string) when the motor is activated. An armor- protected insulated power and control cable connects the motor to a control box positioned at a surface of a reservoir and various sensors provide feedback for the unit. Methods of using this tool are also provided.
A method for producing heavy oil, the method including testing a plurality of samples either from a reservoir play or simulating a reservoir play in a temperature and pressure controlled gravity drainage experiment. Test injection fluids are injected into the samples at a reservoir temperature and pressure and Cumulative Oil Production (COP) or Recovery Factor (RF) or similar feature measured over time. An injection profile is obtained by selecting n injection fluids based on a best COP or RF at a given time Tn, wherein n is a number of fluid injection stages and switching to an n+1 injection fluid when a rate of change (ROC) in the COP or RF drops at least 25%-75%, but preferably 40-60% or 50%. The injection profile is then implemented in the reservoir to produce heavy oil. Optimized injection profiles for certain reservoirs are also provided.
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/30 - Specific pattern of wells, e.g. optimizing the spacing of wells
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Method of monitoring produced water at each perforation or entry point by real time ion sensor deployed downhole to measure the content of water soluble ions. Methods of determining and differentiating nature of water breakthrough in oil production; such as between cycled injection water through a void space conduit, matrix swept injection water and formation water, especially as relates to offshore oil production. Real time ion sensors are deployed and when compared with known standards are used to monitor and remediate water breakthrough, prevent scale deposition, and the like.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 43/119 - Perforators; Permeators - Details, e.g. for locating perforating place or direction
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 47/10 - Locating fluid leaks, intrusions or movements
Method of monitoring produced water at each perforation or entry point by real time ion sensor deployed downhole to measure the content of water soluble ions. Methods of determining and differentiating nature of water breakthrough in oil production; such as between cycled injection water through a void space conduit, matrix swept injection water and formation water, especially as relates to offshore oil production. Real time ion sensors are deployed and when compared with known standards are used to monitor and remediate water breakthrough, prevent scale deposition, and the like.
Methods of determining if a test fluid is inert to reservoir oil at RTP, by assaying a composition, density and bubble or dew point of live oil to generate a first dataset, equilibrating a sample of live oil with a test fluid at RTP to generate an oil phase; assaying a composition, density and bubble or dew point of the oil phase to generate a second dataset; comparing the first and second datasets, wherein significant changes in the datasets indicate that the test fluid is not inert to reservoir oil at RTP. By contrast, if there are no significant changes, the test fluid is inert, and would therefore be suitable to collecting core samples at RTP. Various options for inert fluids are also provided.
Methods of determining if a test fluid is inert to reservoir oil at RTP, by assaying a composition, density and bubble or dew point of live oil to generate a first dataset, equilibrating a sample of live oil with a test fluid at RTP to generate an oil phase; assaying a composition, density and bubble or dew point of the oil phase to generate a second dataset; comparing the first and second datasets, wherein significant changes in the datasets indicate that the test fluid is not inert to reservoir oil at RTP. By contrast, if there are no significant changes, the test fluid is inert, and would therefore be suitable to collecting core samples at RTP. Various options for inert fluids are also provided.
Methods of determining if a test fluid is inert to reservoir oil at RTP, by assaying a composition, density and bubble or dew point of live oil to generate a first dataset, equilibrating a sample of live oil with a test fluid at RTP to generate an oil phase; assaying a composition, density and bubble or dew point of the oil phase to generate a second dataset; comparing the first and second datasets, wherein significant changes in the datasets indicate that the test fluid is not inert to reservoir oil at RTP. By contrast, if there are no significant changes, the test fluid is inert, and would therefore be suitable to collecting core samples at RTP. Various options for inert fluids are also provided.
Gravity driven reverse circulator tools are provided and methods of using same. One tool has nested pipes that when fully nested close a hole in one of the pipes, but when the drillstring is lifted, the pipes partially separate under the force of gravity to expose the hole. The other embodiment is similar, but the hole is hook shaped (hook on top as in a walking cane) and a protrusion from the other pipe fits in the hole. Thus, both lifting and rotation are needed open the tool.
Gravity driven reverse circulator tools are provided and methods of using same. One tool has nested pipes that when fully nested close a hole in one of the pipes, but when the drillstring is lifted, the pipes partially separate under the force of gravity to expose the hole. The other embodiment is similar, but the hole is hook shaped (hook on top as in a walking cane) and a protrusion from the other pipe fits in the hole. Thus, both lifting and rotation are needed open the tool.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
Methods for reducing or reusing emissions and waste from oil and gas processing facilities are described. Specifically, emission and waste streams can be partially oxidized before being treated in a modified syngas fermentation process with parallel bioreactors to produce commodity chemicals of commercial importance while lowering greenhouse gas emissions. At least one bioreactor is online at all times, offline reactors being emptied to collect product and recharged for use.
C12P 7/08 - Ethanol, i.e. non-beverage produced as by-product or from waste or cellulosic material substrate
C07C 1/24 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon starting from organic compounds containing only oxygen atoms as hetero atoms by elimination of water
C01B 3/36 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents using oxygen or mixtures containing oxygen as gasifying agents
Methods for reducing or reusing emissions and waste from oil and gas processing facilities are described. Specifically, emission and waste streams can be partially oxidized before being treated in a modified syngas fermentation process with parallel bioreactors to produce commodity chemicals of commercial importance while lowering greenhouse gas emissions. At least one bioreactor is online at all times, offline reactors being emptied to collect product and recharged for use.
Methods for reducing or reusing emissions and waste from oil and gas processing facilities are described. Specifically, emission and waste streams can be partially oxidized before being treated in a modified syngas fermentation process with parallel bioreactors to produce commodity chemicals of commercial importance while lowering greenhouse gas emissions. At least one bioreactor is online at all times, offline reactors being emptied to collect product and recharged for use.
The invention relates to the introduction of pressurized fluid, e.g. acid, into a subsea well directly from a vessel (33). A fluid injection assembly (20) is fitted to the top of a subsea Xmas tree (3), the assembly (20) including fail safe closed valve (21) which is controlled via a hydraulic line (31) from the vessel. The hose and assembly and valve are designed with an internal bore allowing a large diameter ball to be dropped (required for acid stimulation). The subsea subsea control module (8) on the Xmas tree is controlled from the producing platform.
E21B 33/076 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
E21B 43/27 - Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 34/04 - Valve arrangements for boreholes or wells in well heads in underwater well heads
Gravity driven reverse circulator tools are provided and methods of using same. One tool has nested pipes that when fully nested close a hole in one of the pipes, but when the drillstring is lifted, the pipes partially separate under the force of gravity to expose the hole. The other embodiment is similar, but the hole is hook shaped (hook on top as in a walking cane) and a protrusion from the other pipe fits in the hole. Thus, both lifting and rotation are needed open the tool.
A core-in-shell heat exchanger including a shell having an interior shell portion operable to receive a cooling fluid therein and at least one formed plate heat exchanger (FPHE) core operably arranged within the interior shell portion. The FPHE core includes an inlet coupled with a feed stream, a plurality of feed layers fluidly coupled with the inlet, and a plurality of cooling layers fluidly coupled with the interior shell portion and operable to receive at least a portion of the cooling fluid therein.
F28D 1/03 - Heat-exchange apparatus having stationary conduit assemblies for one heat-exchange medium only, the media being in contact with different sides of the conduit wall, in which the other heat-exchange medium is a large body of fluid, e.g. domestic or mo with the heat-exchange conduits immersed in the body of fluid with plate-like or laminated conduits
F28D 7/16 - Heat-exchange apparatus having stationary tubular conduit assemblies for both heat-exchange media, the media being in contact with different sides of a conduit wall the conduits being arranged in parallel spaced relation
100.
FORMED PLATE CORE-IN-SHELL AND MULTI-PASS EXCHANGERS
A core-in-shell heat exchanger including a shell having an interior shell portion operable to receive a cooling fluid therein and at least one formed plate heat exchanger (FPHE) core operably arranged within the interior shell portion. The FPHE core includes an inlet coupled with a feed stream, a plurality of feed layers fluidly coupled with the inlet, and a plurality of cooling layers fluidly coupled with the interior shell portion and operable to receive at least a portion of the cooling fluid therein.
F28D 1/03 - Heat-exchange apparatus having stationary conduit assemblies for one heat-exchange medium only, the media being in contact with different sides of the conduit wall, in which the other heat-exchange medium is a large body of fluid, e.g. domestic or mo with the heat-exchange conduits immersed in the body of fluid with plate-like or laminated conduits
F28D 7/16 - Heat-exchange apparatus having stationary tubular conduit assemblies for both heat-exchange media, the media being in contact with different sides of a conduit wall the conduits being arranged in parallel spaced relation
F28D 1/00 - Heat-exchange apparatus having stationary conduit assemblies for one heat-exchange medium only, the media being in contact with different sides of the conduit wall, in which the other heat-exchange medium is a large body of fluid, e.g. domestic or mo
F28D 7/00 - Heat-exchange apparatus having stationary tubular conduit assemblies for both heat-exchange media, the media being in contact with different sides of a conduit wall
F28D 9/00 - Heat-exchange apparatus having stationary plate-like or laminated conduit assemblies for both heat-exchange media, the media being in contact with different sides of a conduit wall
F28F 3/00 - Plate-like or laminated elements; Assemblies of plate-like or laminated elements
