Настройки

Укажите год
-

Небесная энциклопедия

Космические корабли и станции, автоматические КА и методы их проектирования, бортовые комплексы управления, системы и средства жизнеобеспечения, особенности технологии производства ракетно-космических систем

Подробнее
-

Мониторинг СМИ

Мониторинг СМИ и социальных сетей. Сканирование интернета, новостных сайтов, специализированных контентных площадок на базе мессенджеров. Гибкие настройки фильтров и первоначальных источников.

Подробнее

Форма поиска

Поддерживает ввод нескольких поисковых фраз (по одной на строку). При поиске обеспечивает поддержку морфологии русского и английского языка
Ведите корректный номера.
Ведите корректный номера.
Ведите корректный номера.
Ведите корректный номера.
Укажите год
Укажите год

Применить Всего найдено 42. Отображено 36.
06-07-2017 дата публикации

METHOD OF FRACTURING A SUBTERRANEAN FORMATION USING MICRONIZED BARITE PARTICLES

Номер: US20170190955A1

A drilling fluid composition that contains micronized barite particles with a particle size in the range of 1 to 5 μm, and also a method of fracturing a subterranean formation using the drilling fluid composition. Various embodiments of the micronized barite particles and the method of making thereof, the drilling fluid composition, and the method of fracturing a subterranean formation are also provided. 1: A method of fracturing a subterranean formation , comprising: micronized barite particles with a particle size in the range of 1 to 5 μm;', 'an aqueous base fluid; and', 'a viscosifier,', 'wherein the micronized barite particles are present in the drilling fluid composition at a concentration in the range of 1 wt % to 50wt %, relative to the total weight of the drilling fluid composition., 'injecting a drilling fluid composition into the subterranean formation through a wellbore to fracture the subterranean formation and form fissures in the subterranean formation, wherein the drilling fluid composition comprises2: The method of claim 1 , further comprising:injecting a proppant into the subterranean formation through the wellbore to deposit the proppant in the fissures.3: The method of claim 1 , further comprisingcirculating the drilling fluid composition within the wellbore after the injecting.4: The method of claim 1 , wherein the drilling fluid composition is injected at a pressure of at least 5 claim 1 ,000 psi to fracture the subterranean formation.5: The method of claim 1 , wherein the viscosifier is bentonite.6: The method of claim 1 , wherein the drilling fluid composition has a plastic viscosity of 14 to 18 cP at a temperature of 80 to 90° F.7: The method of claim 1 , wherein the drilling fluid composition has a plastic viscosity of 4.5 to 7.0 cP at a temperature of 200 to 280° F.8: The method of claim 1 , wherein the drilling fluid composition has a density of 12 to 14 ppg at a temperature of 80 to 90° F.9: The method of claim 1 , wherein the drilling ...

Подробнее
21-01-2021 дата публикации

Cement compositions containing phyllosilicate and methods of use

Номер: US20210017083A1

Cement compositions containing a hydraulic cement, a synthetic phyllosilicate (e.g. Laponite®), and silica flour. The cement compositions may optionally include other additives such as an expandable agent, a defoamer, and a fluid loss controller. Cement slurries and wellbore cements made therefrom are also specified. The inclusion of the synthetic phyllosilicate has enhanced the mechanical strength, improved the density homogeneity, as well as decreased the permeability of the wellbore cement, making it suitable for cementing oil and gas wells under high pressure and high temperature (HPHT) conditions.

Подробнее
24-01-2019 дата публикации

Method of producing micronized barite particles

Номер: US20190023976A1

A drilling fluid composition that contains micronized barite particles with a particle size in the range of 1 to 5 μm, and also a method of fracturing a subterranean formation using the drilling fluid composition. Various embodiments of the micronized barite particles and the method of making thereof, the drilling fluid composition, and the method of fracturing a subterranean formation are also provided.

Подробнее
25-02-2021 дата публикации

Weighted drilling fluid containing organophilic phyllosilicate

Номер: US20210054255A1
Автор: Salaheldin ELKATATNY

A drilling fluid formulation is provided, which includes a fluid phase, an organophilic phyllosilicate as an anti-sagging additive, and a weighting agent (e.g. barite). The organophilic phyllosilicate contains an ion-exchange reaction product of a clay material (e.g. smectite) and quaternary ammonium cations. The organophilic phyllosilicate is effective in preventing barite sagging as demonstrated by low sag factor when drilling at elevated temperatures. Rheology properties of the drilling fluid including gel strength, yield point, plastic viscosity, and storage modulus are also specified.

Подробнее
19-03-2020 дата публикации

METHOD FOR REMOVING IRON SULFIDE AND CALCIUM CARBONATE SCALE

Номер: US20200087568A1

A method of removing a heterogeneous scale from a surface in fluid communication with a wellbore and/or subterranean formation comprising contacting the scale with a composition comprising tetrakis(hydroxmethyl)phosphonium sulfate (THPS) and N-(-hydroxyethyl)ethylenediaminetriacetic acid (THEDTA) to dissolve the scale having a pH in the range of about 6.0 to 8.0. The composition is suitable to remove iron sulfide and calcium carbonate scale in the absence of corrosion resistance at a temperature up to about ° C. Also, the composition may be used remove scale from surface pipe line and other petroleum oil handling equipment. 1: A composition , comprising:an amount of tetrakis(hydroxmethyl)phosphonium sulfate (TRPS) in the range of 10 wt. % to 40 wt. %, andone or more chelating agents selected from the group consisting of diethylenetriamine pentacetic acid (DTPA), N-(2-hydroxyethyl)ethylenediaminetriacetic acid (HEDTA), ethylenediaminetetracetic acid (EDTA), N,N-bis(carboxymethyl)glutamic acid (GLDA), 1,2-cyclohexyldiaminetetraacetinc acid (CDTA), N,N-bis(carboxymethyl)methylglycine (MGDA), and salts thereof in an amount in the range of 5 wt. % to 40%, wherein wt. % is based on the total weight of the composition,wherein the composition has pH in the range of about 6.0 to about 8.0.2: The composition of claim 1 , therein the composition has a pH of 6.5±0.3.3: The composition of claim 1 , wherein the composition further comprises at least one converting agent selected from the group consisting of potassium carbonate (KCO) claim 1 , potassium formate (HCOOK) claim 1 , potassium hydroxide (KOH) claim 1 , potassium chloride (KCl) claim 1 , cesium formate (HCOOCs) claim 1 , and cesium chloride (CsCl).4: The composition of claim 1 , wherein the composition has no corrosion inhibitor.5: The composition of claim 1 , wherein the chelating agent is HEDTA.6: The composition of claim 5 , wherein the amount of THPS is 25 wt. % and the amount of HEDTA is 15 wt. %.7: The composition ...

Подробнее
02-04-2020 дата публикации

METHOD OF PRODUCING SODIUM BENTONITE

Номер: US20200102226A1

Method of converting calcium bentonite to sodium bentonite that is suitable for use as drilling mud or a cement additive. The method comprises preparing a suspension comprising sea water and calcium bentonite at a pH in the range of 8-11, and continuously heating and stirring the suspension for a time in the range of 12 hours to 36 hours. Additives such as soda ash and sodium salt of ethylenediamineteraraacetc acid (EDTA) may be added to the suspension to improve the properties of the product sodium bentonite. 1: A method of producing sodium bentonite having a Na/Ca molar ratio of at least 2.5 comprising:mixing calcium bentonite with sea water to form a suspension at final bentonite concentration in the range of 2 wt. % to 15 wt. % of the total weight of the sea water,adjusting the pH of the suspension in the range of 8.0 to 11,heating the suspension to a temperature in the range of 80 to 100° C. with stirring for a time in the range of 12 to 72 hours, andfiltering and oven drying the product sodium bentonite.2: The method of claim 1 , wherein the sea water is from the Red Sea claim 1 , Arabian Gulf claim 1 , Mediterranean Sea claim 1 , or sea water outflow from sea water desalination plant.3: The method of claim 1 , wherein the sea water contains at least 12000 ppm sodium ion.4: The method of claim 1 , further comprising adding sodium carbonate.5: The method of further comprising stirring the suspension for a time in the range of 10 to 30 minutes prior to adding the sodium carbonate.6: The method of claim 4 , wherein the sodium carbonate and the calcium bentonite are in a ratio in the range of 1:11 to 1:45 by weight.7: The method of claim 1 , wherein the pH is in the range of 9.0 to 10.0.8: The method of claim 1 , wherein the suspension is heated to about 100° C.9: The method of claim 8 , wherein the suspension is heated continuously for a time in the range 24 hours to 48 hours.10: The method of claim 8 , wherein the suspension is stirred at a rate in the range of ...

Подробнее
25-04-2019 дата публикации

Method for making a drilling fluid composition and fracturing a subterranean formation

Номер: US20190119561A1

A drilling fluid composition that contains micronized barite particles with a particle size in the range of 1 to 5 μm, and also a method of fracturing a subterranean formation using the drilling fluid composition. Various embodiments of the micronized barite particles and the method of making thereof, the drilling fluid composition, and the method of fracturing a subterranean formation are also provided.

Подробнее
25-04-2019 дата публикации

Method of forming a mixture of barite particles, chelating agent and bentonite for fracturing

Номер: US20190119562A1

A drilling fluid composition that contains micronized barite particles with a particle size in the range of 1 to 5 μm, and also a method of fracturing a subterranean formation using the drilling fluid composition. Various embodiments of the micronized barite particles and the method of making thereof, the drilling fluid composition, and the method of fracturing a subterranean formation are also provided.

Подробнее
29-09-2022 дата публикации

METHOD AND SYSTEM FOR RATE OF PENETRATION OPTIMIZATION USING ARTIFICIAL INTELLIGENCE TECHNIQUES

Номер: US20220307365A1
Принадлежит:

A method of automatic optimization of ROP. The method obtains a plurality of drilling surface parameters for a field of interest, and determines an UCS data and a MSE data for a targeted formation based on well logs. The method further trains a ML model using the drilling surface parameters as inputs, and outputs a plurality of weights for drilling parameters in a ROP equation and in a Teale's MSE equation for the field of interest. The method further combines the ML ROP equation with the Teale's MSE equation to determine a plurality of optimum drilling parameters by simultaneously solving the set of ML ROP equation and the Teale's MSE equation. Furthermore, the method generates a work order to adjust the drilling parameters and cause display of the work order and the determined optimum drilling parameters in a user interface of a client device. 1. A method for automatic optimization of rate of penetration (ROP) , the method comprising:obtaining, by a computer processor, a plurality of drilling surface parameters for a field of interest;identifying, by a computer processor, an undefined compressive strength (UCS) data for a targeted formation based on well logs;calculating, by a computer processor, a mechanical specific energy (MSE) data based on the identified UCS data for the targeted formation of interest;filtering, by a computer processor, the calculated MSE data based on the identified UCS data with a small range for the targeted formation of interest;training, by a computer processor, a machine learning model using the drilling surface parameters as inputs;outputting, by a computer processor, a plurality of weights for drilling parameters in a ROP equation derived by using the trained machine learning model for the field of interest, wherein the drilling surface parameters are used as inputs;determining, by a computer processor, a plurality of weights for drilling parameters in a Teale's MSE equation for the field of interest, wherein the drilling surface ...

Подробнее
30-05-2019 дата публикации

System, apparatus, and method for determing characteristics of rock samples

Номер: US20190162644A1

The disclosed subject matter broadly involves a device and a method for determining characteristics of a rock sample. The rock sample can be provided in a sample receptacle. Length of the rock sample can be automatically determined when the rock sample is in the sample receptacle. A current can be provided through the rock sample, which, along with the determined length, can be used to determine one or more of resistance-, porosity-, and permeability-related characteristics of the rock sample.

Подробнее
08-07-2021 дата публикации

METHOD OF REMOVING IRON-CONTAINING SCALE FROM A WELLBORE, PIPE, OR SURFACE USING A BIODEGRADABLE DESCALER SOLUTION

Номер: US20210207019A1

A method of removing iron-containing scale from a wellbore, pipe, or metal-containing surface involving contacting the iron-containing scale with a biodegradable descaler solution of water, hydrochloric acid, formic acid, citric acid, a corrosion inhibitor, a corrosion inhibitor intensifier, and a surfactant. The method is performed at a pressure of 14 to 400 psi and a temperature of 100 to 150° C. The method removes iron-containing scale made of iron sulfide, iron carbonate, iron oxyhydroxide, and calcium carbonate. The method meets industry standard steel corrosion rates of less than 0.049 lb/ftper day. Also disclosed is a biodegradable descaler solution of water, hydrochloric acid, formic acid, citric acid, a corrosion inhibitor, a corrosion inhibitor intensifier, and a surfactant that meets OECD 301B thresholds for ready biodegradability. 1: A method for removing an iron-containing scale from a wellbore , pipe , or other metal-containing surface , the method comprising: 55.75 to 80.49 wt % of water,', '16.0 to 22.5 wt % of hydrochloric acid,', '0.75 to 7.5 wt % of formic acid,', '0.75 to 7.5 wt % of citric acid,', '1.0 to 3.0 wt % of a corrosion inhibitor,', '1.0 to 3.0 wt % of a corrosion inhibitor intensifier, and', '0.01 to 0.75 wt % of a surfactant, each based on a total weight of the biodegradable descaler solution;, 'contacting the iron-containing scale with a biodegradable descaler solution comprising'}wherein the biodegradable descaler solution is contacted with the iron-containing scale at a pressure of 14 to 400 psi, andwherein the iron-containing scale has a solubility of 75 to 95 g/L in the biodegradable descaler solution at a temperature of 100 to 150° C.2: The method of claim 1 , wherein the iron-containing scale comprises iron sulfide claim 1 , iron carbonate claim 1 , iron oxyhydroxide claim 1 , and calcium carbonate.3: The method of claim 2 , wherein the iron sulfide is one or more selected from the group consisting of pyrrhotite (FeS) claim 2 , ...

Подробнее
08-07-2021 дата публикации

METHOD OF REMOVING CALCIUM-CONTAINING WATER-BASED FILTER CAKE USING A BIODEGRADABLE ACID SOLUTION

Номер: US20210207020A1

A method of removing calcium-containing water-based filter cake from a wellbore involving contacting the calcium-containing filter cake with a biodegradable acid solution of water, hydrochloric acid, formic acid, citric acid, and a surfactant. The method is performed at a pressure of 200 to 400 psi and a temperature of 50 to 125° C. The method removes calcium-containing filter cake made of water, calcium carbonate, a polymer or starch and a clay. The method meets industry standard steel corrosion rates of less than 0.049 lb/ftper day. Also disclosed is a biodegradable acid solution of water, hydrochloric acid, formic acid, citric acid, and a surfactant that meets OECD 301B thresholds for ready biodegradability. 1: A method for removing a calcium-containing filter cake from a wellbore , the method comprising: 69.5 to 93.375 wt % of water,', '5 to 20 wt % of hydrochloric acid,', '0.75 to 7.5 wt % of formic acid,', '0.75 to 7.5 wt % of citric acid, and', '0.0075 to 0.75 wt % of a surfactant, each based on a total weight of the biodegradable acid solution,, 'contacting the calcium-containing filter cake with a biodegradable acid solution comprising'}wherein the biodegradable acid solution is contacted with the calcium-containing filter cake at a pressure of 200 to 400 psi, andwherein the calcium-containing filter cake comprises water, calcium carbonate, a polymer or starch, and a clay.2: The method of claim 1 , wherein the biodegradable acid solution has a density of 0.90 to 1.25 g/cmat 20 to 30° C.3: The method of claim 1 , wherein the biodegradable acid solution has a viscosity of 1.5 to 1.7 cP at 20 to 30° C.4: The method of claim 1 , wherein the biodegradable acid solution has a surface tension of 30 to 33 mN/m at 20 to 30° C.5: The method of claim 1 , wherein the biodegradable acid solution has a pH of −1.5 to −1.1 at 20 to 30° C.6: The method of claim 1 , wherein the calcium-containing filter cake is substantially free of an oil.7: The method of claim 1 , wherein ...

Подробнее
22-07-2021 дата публикации

METHOD OF REMOVING CALCIUM CARBONATE-CONTAINING OIL-BASED FILTER CAKE USING A BIODEGRADABLE ACID SOLUTION

Номер: US20210222050A1

A method of removing calcium carbonate-containing oil-based filter cake from a wellbore involving contacting the calcium carbonate-containing oil-based filter cake with a biodegradable acid solution of water, hydrochloric acid, formic acid, citric acid, a surfactant, and a glycol ether mutual solvent. The method is performed at a pressure of 200 to 400 psi and a temperature of 50 to 125° C. The method removes calcium carbonate-containing oil-based filter cake made of a water-in-oil emulsion, calcium carbonate, a primary emulsifier, a secondary emulsifier, a contamination treatment agent, a viscosity control agent, a filtration control agent. The method meets industry standard steel corrosion rates of less than 0.049 lb/ftper day. Also disclosed is a biodegradable acid solution of water, hydrochloric acid, formic acid, citric acid, a surfactant, and a glycol ether mutual solvent that meets OECD 301B thresholds for ready biodegradability. 1: A method for removing a calcium carbonate-containing oil-based filter cake from a wellbore face or geological formation material , the method comprising:contacting the calcium carbonate-containing oil-based filter cake with a biodegradable acid solution comprising:61.75 to 92.74 wt % of water,5.0 to 20.0 wt % of hydrochloric acid,0.75 to 5.0 wt % of formic acid,0.75 to 5.0 wt % of citric acid,0.75 to 7.5 wt % of a glycol ether mutual solvent,0.01 to 0.75 wt % of a surfactant, each based on a total weight of the biodegradable acid solution,wherein the biodegradable acid solution is contacted with the calcium carbonate-containing oil-based filter cake at a pressure of 200 to 400 psi, andwherein the calcium carbonate-containing oil-based filter cake comprises petroleum or refined petroleum, and calcium carbonate.2: The method of claim 1 , wherein the calcium carbonate-containing oil-based filter cake further comprises water.3: The method of claim 2 , wherein the water is present in the form of a water-in-oil emulsion.4: The method of ...

Подробнее
05-09-2019 дата публикации

METHOD OF DRILLING A SUBTERRANEAN GEOLOGICAL FORMATION

Номер: US20190270925A1

A method of drilling a subterranean geological formation having a permeability of no more than 0.1 mD with a drilling fluid comprising a continuous phase, a viscosifier, a weighting agent, and sodium silicate, wherein the sodium silicate is present in the drilling fluid at a concentration of 0.01-0.2% by weight, relative to the total weight of the drilling fluid. Various combinations of embodiments of the drilling fluid and the method of drilling the subterranean geological formation are provided. 1. A method of drilling a subterranean geological formation with a permeability of no more than 0.1 millidarcy , the method comprising:drilling the subterranean geological formation to form a wellbore therein; andcirculating a drilling fluid in the wellbore, a continuous phase selected from the group consisting of a water-based fluid and an oil-based fluid,', 'a viscosifier,', 'a weighting agent, and', 'sodium silicate, which is present in the drilling fluid at a concentration of 0.01-0.2% by weight, relative to the total weight of the drilling fluid,', 'wherein the drilling fluid does not contain a retarder; and, 'wherein the drilling fluid compriseswherein during the circulating a filter cake comprising the weighting agent is formed on a wall of the wellbore.2. The method of claim 1 , wherein the sodium silicate is present in the drilling fluid at a concentration of 0.06-0.08% by weight claim 1 , relative to the total weight of the drilling fluid.3. The method of claim 1 , wherein the subterranean geological formation is a sandstone formation.4. The method of claim 1 , wherein circulating the drilling fluid in the wellbore is carried out for no more than 1 hour.5. The method of claim 1 , wherein the viscosifier is bentonite claim 1 , which is present in the drilling fluid at a concentration of 0.1-10% by weight claim 1 , relative to the total weight of the drilling fluid.6. The method of claim 1 , wherein the weighting agent is barite claim 1 , which is present in the ...

Подробнее
08-10-2020 дата публикации

WATER-BASED DRILLING, COMPLETION, AND WORKOVER FLUID COMPOSITION WITH REDUCED BARITE SAGGING

Номер: US20200317981A1

An drilling mud composition is described, which includes an aqueous base fluid, a viscosifier, and a weighting material. The drilling mud composition also includes an anti-sagging agent that comprises a dimethylamino methyl ester, such as methyl 5-(dimethylamino)-2-methyl-5-oxopentanoate. The anti-sagging agent may be used to prevent barite sagging, where barite is used as a weighting material. Small amounts of the anti-sagging agent may be used to maintain a low sag factor while drilling, and without causing unwanted increases in viscosity. The anti-sagging agent is effective for both vertical and inclined wellbores. 1. A drilling mud composition , comprising:an aqueous base fluid;a viscosifier;a weighting agent;a fluid loss control additive, and an anti-sagging agent comprising a dimethylamino methyl ester.2. The drilling mud composition of claim 1 , wherein the dimethylamino methyl ester is present at a volume percentage in a range of 0.25-3.0 vol % claim 1 , relative to a total volume of the aqueous base fluid.3. The drilling mud composition of claim 1 , wherein the dimethylamino methyl ester has a molecular weight in a range of 150-250 g/mol.4. The drilling mud composition of claim 1 , wherein the dimethylamino methyl ester is methyl 5-(dimethylamino)-2-methyl-5-oxopentanoate.5. The drilling mud composition of claim 1 , wherein the weighting agent is barite.6. The drilling mud composition of claim 5 , wherein the barite is in the form of particles having a mean diameter in a range of 20-70 μm.7. The drilling mud composition of claim 1 , wherein the anti-sagging agent further comprises LiCl.8. The drilling mud composition of claim 1 , which has a density in a range of 8.34-20 ppg.9. The drilling mud composition of claim 1 , wherein a volume concentration of the dimethylamino methyl ester is 0.2-3.0 vol % relative to a total volume of the aqueous base fluid.10. The drilling mud composition of claim 1 , further comprising at least one additive selected from the ...

Подробнее
24-10-2019 дата публикации

AUTOMATED MARCH FUNNEL FOR OIL AND GAS FIELD OPERATIONS

Номер: US20190323935A1

The invention is directed to an automated Marsh funnel and Marsh funnel apparatus or system, and an automated method for measuring the Marsh funnel time and density of drilling muds and calculating other rheological properties from Marsh funnel time and mud weight. The system measures and reports rheological properties of drilling muds in real time and faster, more conveniently, and more accurately than conventional manual methods. 1. An automated method for determining Marsh funnel time and drilling mud weight , comprising:transferring of a predetermined amount of a drilling mud via at least one conduit from a holding tank to a Marsh funnel every 2 to 30 minutes, wherein the predetermined amount is dispensed via opening and closing of an intake valve between the at least one conduit and the Marsh funnel under the control of an electronic controller in communication with a fluid level sensor;releasing of a second predetermined amount of drilling mud in the Marsh funnel out the lower end of the Marsh funnel under the control of the electronic controller in communication with a second fluid level sensor or time sensor that measures a time for the second predetermined amount of drilling mud to leave the Marsh funnel (Marsh funnel time),weighing the second predetermined amount of drilling mud on an automated weighing device in communication with the electronic controller,thereby determining the Marsh funnel time and drilling mud weight of the second predetermined volume of drilling mud,transmitting the Marsh funnel time and drilling mud weight to an electronic data processor,displaying, indicating, receiving or recording of the Marsh funnel time and weight of the sample on a screen or other output device, andcleaning and/or drying the Marsh funnel and the weighing device prior to a subsequent automated transfer of a predetermined amount of a drilling mud into the Marsh funnel by releasing residual mud in the Marsh funnel by reopening the automated valve at the bottom of ...

Подробнее
22-10-2020 дата публикации

IRON CONTROL COMPOSITION, MAKE, AND USE IN CARBONATE STIMULATION

Номер: US20200332178A1

Well stimulating fluids and methods use a first and a second chelating agent, e.g., diethylene triamine pentaacetic acid (DTPA), glutamic diacetic acid (GLDA), and/or hydroxyethyl ethylene diamine triacetic acid (HEDTA), particularly in amounts of from 1 to 10 wt. %, to control iron precipitation during the stimulation process. Such fluids can stabilize iron ions without precipitation to manage the efficiency and performance of the stimulation fluid. Such stimulation fluids can be used with for highly concentrated HCl solutions, e.g., more than 20 up to 28 wt. % or more, that is useful in emulsified acid formulations in acid fracturing or acidizing of carbonate formations. 2: The fluid of claim 1 , wherein the HCl is present in a concentration of at least 22 wt. % claim 1 , relative to the total stimulation fluid weight.3: The fluid of claim 1 , comprising diethylenetriamine pentaacetic acid as the first chelating agent.4: The fluid of claim 1 , comprising hydroxyethyl ethylenediamine triacetic acid as the second chelating agent.5: The fluid of claim 1 , comprising glutamic diacetic acid as the second chelating agent.6: The fluid of claim 1 , comprising:diethylenetriamine pentaacetic acid as the first chelating agent; andglutamic diacetic acid as the second chelating agent.7: The fluid of claim 1 , which is suitable to maintain up to 3000 ppm iron ions in the fluid solubilized for at least 3 days.8: The fluid of claim 7 , wherein the iron ions remain solubilized up to a pH of 4.9: The fluid of claim 1 , wherein the first chelating agent is present in an amount of from 1.5 to 3.5 wt. % claim 1 , relative to the total stimulation fluid weight.10: The fluid of claim 1 , wherein the second chelating agent is present in an amount of from 1.5 to 3.5 wt. % claim 1 , relative to the total stimulation fluid weight.11: The fluid of claim 1 , wherein the first and the second chelating agents are present in a range of from 2 to 2.5 wt. % claim 1 , relative to the total ...

Подробнее
13-09-2022 дата публикации

Method of removing iron-containing scale from a wellbore, pipe, or surface using a biodegradable descaler solution

Номер: US11441064B2

A method of removing iron-containing scale from a wellbore, pipe, or metal-containing surface involving contacting the iron-containing scale with a biodegradable descaler solution of water, hydrochloric acid, formic acid, citric acid, a corrosion inhibitor, a corrosion inhibitor intensifier, and a surfactant. The method is performed at a pressure of 14 to 400 psi and a temperature of 100 to 150° C. The method removes iron-containing scale made of iron sulfide, iron carbonate, iron oxyhydroxide, and calcium carbonate. The method meets industry standard steel corrosion rates of less than 0.049 lb/ft 2 per day. Also disclosed is a biodegradable descaler solution of water, hydrochloric acid, formic acid, citric acid, a corrosion inhibitor, a corrosion inhibitor intensifier, and a surfactant that meets OECD 301B thresholds for ready biodegradability.

Подробнее
16-08-2022 дата публикации

Method of removing calcium carbonate-containing oil-based filter cake using a biodegradable acid solution

Номер: US11414589B2

A method of removing calcium carbonate-containing oil-based filter cake from a wellbore involving contacting the calcium carbonate-containing oil-based filter cake with a biodegradable acid solution of water, hydrochloric acid, formic acid, citric acid, a surfactant, and a glycol ether mutual solvent. The method is performed at a pressure of 200 to 400 psi and a temperature of 50 to 125° C. The method removes calcium carbonate-containing oil-based filter cake made of a water-in-oil emulsion, calcium carbonate, a primary emulsifier, a secondary emulsifier, a contamination treatment agent, a viscosity control agent, a filtration control agent. The method meets industry standard steel corrosion rates of less than 0.049 lb/ft 2 per day. Also disclosed is a biodegradable acid solution of water, hydrochloric acid, formic acid, citric acid, a surfactant, and a glycol ether mutual solvent that meets OECD 301B thresholds for ready biodegradability.

Подробнее
23-07-2019 дата публикации

Method of forming a mixture of barite particles, chelating agent and bentonite for fracturing

Номер: US10358593B2

A drilling fluid composition that contains micronized barite particles with a particle size in the range of 1 to 5 μm, and also a method of fracturing a subterranean formation using the drilling fluid composition. Various embodiments of the micronized barite particles and the method of making thereof, the drilling fluid composition, and the method of fracturing a subterranean formation are also provided.

Подробнее
08-06-2023 дата публикации

Advanced caliper for a pipe and method of use

Номер: US20230176015A1

A robotic device and method for inspecting a pipeline to assess metal loss, the presence of defects and corrosion effects. The robotic device is an inline inspection tool that can establish a positional address in the pipeline using known positional benchmarks. The robotic device comprises flexible electronic caliper sensors measuring pipe diameter and an elastic foam body to prevent seizing within the pipeline. A removable PCB enables interchangeable operation with in-kind devices of different diameters and/or with the computers, extracting and plotting the data. The method of measurement may use data fusion between different instruments and measurement methodologies.

Подробнее
20-09-2022 дата публикации

Method of producing sodium bentonite

Номер: US11447395B2

Method of converting calcium bentonite to sodium bentonite that is suitable for use as drilling mud or a cement additive. The method comprises preparing a suspension comprising sea water and calcium bentonite at a pH in the range of 8-11, and continuously heating and stirring the suspension for a time in the range of 12 hours to 36 hours. Additives such as soda ash and sodium salt of ethylenediamineteraraacetc acid (EDTA) may be added to the suspension to improve the properties of the product sodium bentonite.

Подробнее
14-09-2023 дата публикации

Calcined saudi calcium bentonite as cement replacement in low-density oil-well cement system

Номер: US20230287256A1

A method to incorporate calcined Saudi calcium bentonite as a low-density cement admixture in oil and gas well applications. Low-density cement systems were designed using the calcined Saudi calcium bentonite in an amount of from 10 to 30 weight % of the admixture to form a low-density cement slurry at a density of from 10 pounds per gallon (ppg) to 15 ppg; and injecting the low-density cement slurry into the well to seal the well from the geological formation; and curing the low-density cement slurry in the well to seal the well from the geological formation.

Подробнее
10-10-2023 дата публикации

Cement compositions containing phyllosilicate and methods of use

Номер: US11780775B2

Cement compositions containing a hydraulic cement, a synthetic phyllosilicate (e.g. Laponite®), and silica flour. The cement compositions may optionally include other additives such as an expandable agent, a defoamer, and a fluid loss controller. Cement slurries and wellbore cements made therefrom are also specified. The inclusion of the synthetic phyllosilicate has enhanced the mechanical strength, improved the density homogeneity, as well as decreased the permeability of the wellbore cement, making it suitable for cementing oil and gas wells under high pressure and high temperature (HPHT) conditions.

Подробнее
07-11-2023 дата публикации

Calcined Saudi calcium bentonite as cement replacement in low-density oil-well cement system

Номер: US11807805B2

A method to incorporate calcined Saudi calcium bentonite as a low-density cement admixture in oil and gas well applications. Low-density cement systems were designed using the calcined Saudi calcium bentonite in an amount of from 10 to 30 weight % of the admixture to form a low-density cement slurry at a density of from 10 pounds per gallon (ppg) to 15 ppg; and injecting the low-density cement slurry into the well to seal the well from the geological formation; and curing the low-density cement slurry in the well to seal the well from the geological formation.

Подробнее
13-02-2024 дата публикации

Use of granite waste powder in lightweight oilwell cement systems; strength analysis

Номер: US11898089B2

A method for treating a well in a hydrocarbon-producing subterranean production zone. The method for treating well-producing hydrocarbons from a subterranean production zone includes dry mixing a granite waste powder (GWP) in a form of rock aggregates and a cement to form a mixture. Then the mixture is added to the cement composition containing water, pre-hydrated sodium bentonite, calcium chloride, a dispersant, and an alcohol-based defoamer to form a cement slurry. The cement slurry is prepared at a density of from 13.5 pounds per gallon (ppg) to 14.5 ppg and contains the GWP in a range of from 5 wt. % to 20 wt. % of the cement slurry. 10 wt. % to 15 wt. % perlite is added into the cement slurry to form a ternary blend which is cured and then the cured product is injected into the well to seal the well at the subterranean production zone.

Подробнее
26-10-2023 дата публикации

Weighted drilling fluid containing metal-modified phyllosilicate

Номер: US20230340316A1

A drilling fluid formulation is provided, which includes an aqueous base fluid, a synthetic modified phyllosilicate as an anti-sagging additive, an inorganic base, and a weighting agent (e.g. barite). The synthetic modified phyllosilicate contains a clay material (e.g. smectite) and a metal selected from ruthenium, rhodium, palladium, osmium, iridium, and platinum. The synthetic modified phyllosilicate is effective in preventing barite sagging as demonstrated by low sag factor when drilling at elevated temperatures. Rheology properties of the drilling fluid including gel strength, yield point, plastic viscosity, and storage modulus are also specified.

Подробнее
09-04-2024 дата публикации

Method and system for rate of penetration optimization using artificial intelligence techniques

Номер: US11952880B2

A method of automatic optimization of ROP. The method obtains a plurality of drilling surface parameters for a field of interest, and determines an UCS data and a MSE data for a targeted formation based on well logs. The method further trains a ML model using the drilling surface parameters as inputs, and outputs a plurality of weights for drilling parameters in a ROP equation and in a Teale's MSE equation for the field of interest. The method further combines the ML ROP equation with the Teale's MSE equation to determine a plurality of optimum drilling parameters by simultaneously solving the set of ML ROP equation and the Teale's MSE equation. Furthermore, the method generates a work order to adjust the drilling parameters and cause display of the work order and the determined optimum drilling parameters in a user interface of a client device.

Подробнее
10-10-2023 дата публикации

Weighted drilling fluid containing metal-modified phyllosilicate

Номер: US11781054B1

A drilling fluid formulation is provided, which includes an aqueous base fluid, a synthetic modified phyllosilicate as an anti-sagging additive, an inorganic base, and a weighting agent (e.g. barite). The synthetic modified phyllosilicate contains a clay material (e.g. smectite) and a metal selected from ruthenium, rhodium, palladium, osmium, iridium, and platinum. The synthetic modified phyllosilicate is effective in preventing barite sagging as demonstrated by low sag factor when drilling at elevated temperatures. Rheology properties of the drilling fluid including gel strength, yield point, plastic viscosity, and storage modulus are also specified.

Подробнее
28-11-2023 дата публикации

Water-based drilling, completion, and workover fluid composition with reduced barite sagging

Номер: US11827837B2

An drilling mud composition is described, which includes an aqueous base fluid, a viscosifier, and a weighting material. The drilling mud composition also includes an anti-sagging agent that comprises a dimethylamino methyl ester, such as methyl 5-(dimethylamino)-2-methyl-5-oxopentanoate. The anti-sagging agent may be used to prevent barite sagging, where barite is used as a weighting material. Small amounts of the anti-sagging agent may be used to maintain a low sag factor while drilling, and without causing unwanted increases in viscosity. The anti-sagging agent is effective for both vertical and inclined wellbores.

Подробнее
24-10-2023 дата публикации

Iron control composition, make, and use in carbonate stimulation

Номер: US11795378B2

Well stimulating fluids and methods may use a first and a second chelating agent, e.g., diethylene triamine pentaacetic acid (DTPA), glutamic diacetic acid (GLDA), and/or hydroxyethyl ethylene diamine triacetic acid (HEDTA), particularly in amounts of from 1 to 10 wt. %, to control iron precipitation during the stimulation process. Such fluids can stabilize iron ions without precipitation to manage the efficiency and performance of the stimulation fluid. Such stimulation fluids can be used with for highly concentrated HCl solutions, e.g., more than 20 up to 28 wt. % or more, that are useful in emulsified acid formulations in acid fracturing or acidizing of carbonate formations.

Подробнее
08-02-2024 дата публикации

Method for drilling a wellbore with a reduced ferrite sag composition

Номер: US20240043733A1

An drilling mud composition is described, which includes an aqueous base fluid, a viscosifier, and a weighting material The drilling mud composition also includes an anti-sagging agent that comprises a dimethylamino methyl ester, such as methyl 5-(dimethylamino)-2-methyl-5-oxopentanoate. The anti-sagging agent may be used to prevent barite sagging, where barite is used as a weighting material. Small amounts of the anti-sagging agent may be used to maintain a low sag factor while drilling, and without causing unwanted increases in viscosity. The anti-sagging agent is effective for both vertical and inclined wellbores.

Подробнее
23-07-2024 дата публикации

Method and system for real-time hole cleaning using a graphical user interface and user selections

Номер: US12044124B2

A method may include obtaining, in real-time, well data regarding a wellbore and drilling fluid data regarding drilling fluid circulating in the wellbore. The method may further include determining, based on the drilling fluid data, a plastic viscosity (PV) value and a yield point (YP) value regarding the drilling fluid. The method may further include determining, based on the well data and the drilling fluid data, an equivalent circulating density (ECD) value of an annulus of the wellbore. The method may further include determining a hole cleaning efficiency (HCE) value based on a hole cleaning model, the PV value, the YP value, and the ECD value. The method may further include determining an adjusted rate of penetration (ROP) value for a drilling operation in the wellbore based on the HCE value and a current ROP value. The method may further include transmitting a command to a drilling system that produces the adjusted ROP value in the drilling operation.

Подробнее
14-09-2023 дата публикации

Use of granite waste powder in lightweight oilwell cement systems; strength analysis

Номер: US20230287257A1

A method for treating a well in a hydrocarbon-producing subterranean production zone. The method for treating well-producing hydrocarbons from a subterranean production zone includes dry mixing a granite waste powder (GWP) in a form of rock aggregates and a cement to form a mixture. Then the mixture is added to the cement composition containing water, pre-hydrated sodium bentonite, calcium chloride, a dispersant, and an alcohol-based defoamer to form a cement slurry. The cement slurry is prepared at a density of from 13.5 pounds per gallon (ppg) to 14.5 ppg and contains the GWP in a range of from 5 wt. % to 20 wt. % of the cement slurry. 10 wt. % to 15 wt. % perlite is added into the cement slurry to form a ternary blend which is cured and then the cured product is injected into the well to seal the well at the subterranean production zone.

Подробнее
13-06-2024 дата публикации

Testing pressure vessel for cured concrete pipe sheath

Номер: US20240192113A1

A testing pressure vessel for permeability testing of a cured concrete sample. The testing pressure vessel includes a cylindrical pressure vessel with a sample injection port and a casing fluid injection port, and a casing fluid outlet port and an outlet port. The testing pressure vessel also includes a hydraulic inlet, and a sleeve positioned adjacent to an inner surface of the cylindrical pressure vessel and the hydraulic inlet. The testing pressure vessel further includes a plurality of pressure ports to measure a pressure exerted on the sleeve. The testing involves applying confining pressure and injection pressure to the cured concrete sample, to have the confining pressure to at least 300 psi higher than the injection pressure until a predetermined injection pressure is achieved. The testing further includes measuring the permeability of the cured concrete sample directly by measuring the pressure exerted on the sleeve.

Подробнее
08-10-2024 дата публикации

Drilling fluid composition and method for removing hydrogen sulfide content using the same

Номер: US12110447B1

A drilling fluid composition includes a base fluid; at least one additive selected from the group consisting of an anti-foaming agent, a fluid-loss additive, a viscosity modifier, a shale stabilizer, an alkali compound, a bridging agent, and a weighting agent; and 0.01 to 0.5 weight percentage (wt. %) of particles of steel slag, based on a total weight of the drilling fluid composition. A method for reducing a hydrogen sulfide (H2S) content of a H2S-containing subterranean formation. A process for removing H2S from a H2S-containing gas composition by the drilling fluid composition.

Подробнее