УСТРОЙСТВО (ВАРИАНТЫ) И СПОСОБ ДЛЯ ОПРЕДЕЛЕНИЯ СКВАЖИННЫХ ПАРАМЕТРОВ

Группа изобретений относится к области исследования скважин, а именно к технологиям определения скважинных параметров. Техническим результатом является повышение качества и точности измерений скважинных параметров. Для чего в одном из вариантов коммуникационная система для определения скважинных параметров содержит сенсорную пробку, выполненную с возможностью размещения в отверстии, проходящем в стенке скважины. Система содержит гильзу, выполненную с возможностью размещения в отверстии, проходящем в стенке скважины, палец, выполненный с возможностью размещения в гильзе. При этом палец выполнен с возможностью расширять гильзу по мере его продвижения в нее, в результате чего гильза уплотняет отверстие. При этом гильза имеет камеру, а палец на своем конце имеет иглу, выполненную с возможностью прокалывания камеры при подаче пальца в гильзу. Система оборудована датчиком для измерения скважинных параметров и электронными схемами, соединенными с датчиком. Система также оборудована скважинным ...

СИСТЕМА ЕДИНСТВЕННОГО ПАКЕРА ДЛЯ ИСПОЛЬЗОВАНИЯ В СТВОЛЕ СКВАЖИНЫ

Группа изобретений относится к системам и способам отбора пластовых текучих сред из конкретной зоны ствола скважины, содержащим единственный пакер, к способам формирования пакера. Обеспечивает увеличенные степени расширения, более высокие перепады давления депрессии, лучшую поддержку пласта в зоне, из которой отбирают пластовые текучие среды. Система отбора текучей среды из конкретной зоны ствола скважины содержит единственный пакер, имеющий внешний слой, расширяющийся в стволе скважины поперек зоны расширения и содержащий множество дренажных отверстий в зоне расширения и множество трубок, соединенных с множеством дренажных отверстий, эластичный надувной баллон, расположенный внутри внешнего слоя, и пару механических крепежных устройств, расположенных на противоположных концах внешнего слоя и имеющих множество поворотных проточных элементов, соединенных с множеством трубок для приспособления к расширению внешнего слоя эластичным надувным баллоном. 4 н. и 21 з.п ф-лы, 19 ил.

СПОСОБ И УСТРОЙСТВО ДЛЯ АНАЛИЗА ФЛЮИДА

Изобретение относится к технологиям проведения оценки подземной формации с помощью скважинного инструмента, размещенного в стволе скважины, проходящей в подземной формации. Техническим результатом является точный анализ флюида в реальном режиме времени в стволе скважины. Устройство для анализа флюида, содержащее испытательную камеру, приспособление для перемещения флюида, нагнетательное средство и, по меньшей мере, один датчик. Испытательная камера образует оценочную полость для приема флюида. Приспособление для перемещения флюида имеет силовое средство, прикладывающее усилие к флюиду, заставляя флюид перемещаться внутри полости. Нагнетательное средство непрерывно изменяет давление флюида. 4 н. и 23 з.п. ф-лы, 8 ил.

СПОСОБ И УСТРОЙСТВО ДЛЯ ОПРЕДЕЛЕНИЯ ОПТИМАЛЬНОЙ СКОРОСТИ ОТКАЧКИ ФЛЮИДА НА ОСНОВЕ ОПРЕДЕЛЯЕМОГО В СКВАЖИНЕ ДАВЛЕНИЯ НАЧАЛА КОНДЕНСАЦИИ

Изобретение относится к спектрометрии в условиях скважины и, в частности, к устройству и способу для определения оптимальной скорости откачки на основе соответствующего скважинным условиям давления начала конденсации или давления насыщения. Техническим результатом является предупреждение, во время отбора проб, выпадения твердых веществ и образования пузырьков, тем самым, сохранение пробы в однофазном состоянии. Устройство содержит приемную камеру для проб, сообщающийся с приемной камерой насос, сообщающееся с пробой средство измерения давления и оптический анализатор, оптически связанный с пробой, обеспечивающие понижение давления в пробе с определением давления, при котором наступает экстремум количества света, проходящего через пробу. 4 н. и 15 з.п. ф-лы, 27 ил.

МОНТАЖНОЕ СОЕДИНЕНИЕ ДЛЯ СКВАЖИННОГО ИНСТРУМЕНТА

Раскрыто монтажное соединение (104), предназначенное для соединения множества модулей скважинного инструмента. Модули включают в себя корпус и электрическую линию. Перегородка (224) присоединена к первому модулю (116), который включает в себя первое проходное отверстие, предназначенное для размещения электрического соединительного устройства (242). Первое электрическое соединительное устройство соединено с наружной частью первого модуля с возможностью отсоединения. Оно включает в себя первый соединитель, имеющий первый конец, приспособленный для электрического соединения с электрической линией. Соединительный блок (200) соединен со вторым модулем (118), который включает в себя второе проходное отверстие. Второе проходное отверстие расположено так, чтобы оно находилось по существу напротив первого проходного отверстия, когда первый и второй модули соединены. Второй электрический соединитель расположен во втором проходном отверстии и электрически соединен с электрической линией таким образом ...

УСТРОЙСТВО И СПОСОБ ИЗМЕРЕНИЯ СОДЕРЖАНИЯ ВОДЫ И КОНЦЕНТРАЦИИ СОЛИ В ПОТОКЕ МНОГОФАЗНОГО ФЛЮИДА

Изобретение относится к оборудованию для подводной добычи нефти. Изобретение касается устройства измерения содержания воды и концентрации соли в потоке многофазного флюида в подводном оборудовании для добычи нефти, содержащего: емкостный датчик, находящийся внутри трубной секции (5), через которую проходит поток многофазного флюида, генератор (10) сигналов, подключенный к емкостному датчику; первый измерительный преобразователь (40), выполненный с возможностью измерения напряжения на емкостном датчике; второй измерительный преобразователь (50), выполненный с возможностью измерения тока, проходящего через емкостный датчик; выходной контур (60), выполненный с возможностью, на основе сигналов, сгенерированных первым (40) и вторым (50) измерительными преобразователями, генерировать выходные сигналы (70, 72), которые характеризуют концентрацию соли и содержание воды в потоке многофазного флюида, и блок (80) управления, выполненный с возможностью приема первого и второго выходных сигналов (70 ...

СПОСОБЫ И УСТРОЙСТВО ДЛЯ АНАЛИЗА СКВАЖИННЫХ АСФАЛЬТЕНОВЫХ ГРАДИЕНТОВ И ИХ ПРИМЕНЕНИЕ

Изобретение относится к способу и устройству для описания нефтяного флюида, извлекаемого из углеводородоносной геологической формации. Изобретение имеет применение в приложениях по моделированию пласта-коллектора. Техническим результатом является обеспечение точного определения разделения и/или неравновесного распределения углеводорода в интересующем пласте-коллекторе. Способ и система для описания асфальтеновых градиентов интересующего пласта-коллектора и анализа свойств интересующего пласта-коллектора на основании таких асфальтеновых градиентов. Анализ использует корреляцию, которая связывает концентрацию нерастворимого асфальтена с данными спектрофотометрических измерений, измеренных на глубине. 2 н. и 18 з.п. ф-лы, 4 ил.

ПРОБООТБОРНИК

Полезная модель относится к добыче, сбору, подготовке и транспорту жидких и газовых продуктов и может быть использовано на нефтегазодобывающих, нефтегазоперерабатывающих и нефтетранспортных или иных предприятиях, где производятся работы по отбору проб жидкости из трубопроводов. Пробоотборник содержит корпус в виде присоединительного патрубка, приваренного к трубопроводу и шток с вентилем, отличающийся тем, что содержит пробоотборную трубку с уплотнительным кольцом из полиуретана, имеющим наружный диаметр 10 мм по всей длине и 19.5 мм со стороны присоединительного патрубка, длину от 107 мм до 162 мм в зависимости от диаметра применяемого трубопровода от 60 мм до 89 мм, при этом имеются от 4 до 9 отверстий радиальной конической формы с наружным диаметром 4-6 мм и внутренним диаметром 8-10 мм. Пробоотборник имеет рабочее давление Р=4 МПа. 2 ил. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 178 239 U1 (51) МПК E21B 49/08 (2006.01) G01N 1/00 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ПОЛЕЗНОЙ МОДЕЛИ К ПАТЕНТУ (52) СПК E21B 49/081 (2006.01); E21B 49/10 (2006.01) (21)(22) Заявка: 2017128942, 14.08.2017 (24) Дата начала отсчета срока действия патента: Дата регистрации: 28.03.2018 (45) Опубликовано: 28.03.2018 Бюл. № 10 1 7 8 2 3 9 R U (54) ПРОБООТБОРНИК (57) Реферат: Полезная модель относится к добыче, сбору, подготовке и транспорту жидких и газовых продуктов и может быть использовано на н е ф т е г а з о д о б ы в а ю щ и х , нефтегазоперерабатывающих и нефтетранспортных или иных предприятиях, где производятся работы по отбору проб жидкости из трубопроводов. Пробоотборник содержит корпус в виде присоединительного патрубка, приваренного к трубопроводу и шток с вентилем, отличающийся тем, что содержит пробоотборную Стр.: 1 (56) Список документов, цитированных в отчете о поиске: RU 2299983 C2, 27.05.2007. RU 47971 U1, 10.09.2005. RU 77349 U1, 20.10.2008. RU 49899 U1, 10.12.2005. RU 48362 U1, 10.10.2005. RU 61345 U1, 27.02.2007. RU 51102 U1, 27.01. ...

ПОСТОЯННО ЭКСЦЕНТРИЧЕСКИЙ ОПРОБОВАТЕЛЬ ПЛАСТОВ

... 1. Опробователь пластов для определения пластового давления подземного пласта, пересекаемого стволом скважины, содержащий удлиненный корпус (1) опробователя, опорную пластину (3), выполненную выдвигаемой наружу от поверхности корпуса и поддерживающую зондовое средство (5) для создания канала между внутренней стороной корпуса и пластом, и уплотнительную прокладку (6), присоединенную к зондовому средству, для изоляции канала между внутренней стороной корпуса и пластом, анкерные средства (7) для установки корпуса на горизонте внутри ствола скважины, отличающийся тем, что корпус содержит эксцентрический участок (2), и опорная пластина установлена с возможностью сохранения определенного зазора между корпусом (1) и стенкой (8) ствола скважины при установке корпуса на горизонте в стволе скважины. 2. Опробователь пластов по п.1, отличающийся тем, что дополнительно содержит позиционирующие устройства (4) зонда, установленные на первой стороне эксцентрического участка (2) и выдвигающие опорную пластину ...

СПОСОБ И УСТРОЙСТВО ДЛЯ ОПРЕДЕЛЕНИЯ ОПТИМАЛЬНОЙ СКОРОСТИ ОТКАЧКИ ФЛЮИДА НА ОСНОВЕ ОПРЕДЕЛЯЕМОГО В СКВАЖИНЕ ДАВЛЕНИЯ НАЧАЛА КОНДЕНСАЦИИ

... 1. Устройство для откачки пробы пластового флюида, содержащее приемную камеру для проб, сообщающийся с приемной камерой насос, сообщающееся с пробой средство измерения давления и оптический анализатор, оптически связанный с пробой, обеспечивающие понижение давления в пробе с определением давления, при котором наступает экстремум количества света, проходящего через пробу. 2. Устройство по п.1, содержащее также процессор, позволяющий на основе давления при экстремуме количества проходящего света определять оптимальную скорость откачки, при которой откачка пробы выполняется как можно более быстро без падения давления в пробе ниже значения, соответствующего давлению начала конденсации и/или давлению насыщения. 3. Устройство по п.1, содержащее также процессор, позволяющий определять давление начала конденсации для пробы пластового флюида. 4. Устройство по п.3, в котором процессор позволяет определять оптимальную скорость откачки на основе давления начала конденсации. 5. Устройство по п.1, содержащее ...

УСТРОЙСТВО И СПОСОБЫ ВЫПОЛНЕНИЯ ОПЕРАЦИЙ В СТВОЛЕ СКВАЖИНЫ С ИСПОЛЬЗОВАНИЕМ СКВАЖИННЫХ ИНСТРУМЕНТОВ С ПЕРЕМЕЩАЮЩИМИСЯ СЕКЦИЯМИ

... 1. Способ выполнения операций отбора проб и отбора кернов, согласно которому ! спускают скважинный инструмент на каротажном кабеле в ствол скважины, проходящий в подземный пласт; ! закрепляют скважинный инструмент в стволе скважины, выдвигая фиксирующую опору из скважинного инструмента в контакт со стенкой ствола скважины на первом месте работ в стволе скважины; ! выполняют операцию отбора проб или образцов пластовой текучей среды с использованием инструмента отбора проб, связанного с первой секцией, при этом операцию отбора проб или образцов выполняют на втором месте работ в стволе скважины, когда скважинный инструмент остается закрепленным в стволе скважины на первом месте работ, и при этом второе место работ разнесено с первым местом работ в направлении, параллельном продольной оси скважинного инструмента; и ! перемещают первую секцию скважинного инструмента и вторую секцию скважинного инструмента так, что первая секция скважинного инструмента переводится от второго места работ в направлении ...

СПОСОБ И УСТРОЙСТВО ДЛЯ АНАЛИЗА ФЛЮИДА

... 1. Устройство для анализа флюида, содержащее испытательную камеру, образующую оценочную полость для приема флюида, приспособление для перемещения флюида, имеющее силовое средство, прилагающее усилие к флюиду для перемещения флюида в полости, нагнетательный узел, изменяющий давление флюида непрерывным образом, и по меньшей мере, один датчик, взаимодействующий с флюидом для определения, по меньшей мере, одного параметра флюида при непрерывном изменении давления флюида. 2. Устройство по п.1, в котором испытательная камера является каналом. 3. Устройство по п.2, в котором оценочная полость канала сконфигурирована как петля рециркуляции. 4. Устройство по п.1, в котором испытательная камера содержит канал, обводную петлю, сообщающуюся с каналом и образующую оценочную полость, и по меньшей мере, один клапан, размещенный между каналом и оценочной полостью обводной петли для избирательного отвода флюида в оценочную полость обводной петли из канала. 5. Устройство по п.1, в котором приспособления ...

СПОСОБЫ И УСТРОЙСТВА АНАЛИЗА ФЛЮИДОВ В СКВАЖИНЕ

... 1. Устройство определения характеристик флюида в скважине, содержащее ! модуль анализа флюидов, который содержит: ! проточную линию для направления флюидов, извлеченных из пласта, через модуль анализа флюидов, имеющую первый конец, для ввода флюидов во второй конец, для вывода флюидов из модуля анализа флюидов, ! первое избирательно действующее устройство и второе избирательно действующее устройство, установленные на проточной линии для отделения (отбора) некоторого количества флюидов на участке проточной линии между первым и вторым избирательно действующими устройствами; и ! по меньшей мере один датчик, расположенный на участке проточной линии между первым и вторым избирательно действующими устройствами, для измерения требуемых параметров флюидов в проточной линии. ! 2. Устройство по п.1, отличающееся тем, что по меньшей мере одно из первого и второго избирательно действующих устройств содержит клапан. ! 3. Устройство по п.1, отличающееся тем, что одно из первого и второго избирательного ...

СКВАЖИННЫЕ УСТРОЙСТВА, УПРАВЛЯЕМЫЕ ПО РАДИАЛЬНОМУПОЛОЖЕНИЮ, И СПОСОБЫ ИХ ПРИМЕНЕНИЯ

... 1. Способ выполнения работ в стволе скважины, заключающийся в том, что (а) в скважину вводят устройство, имеющее первый модуль, соединенный с расположенным вблизи него вторым модулем и снабженный управляемым установочным устройством и скважинным прибором, предназначенным для выполнения заданной работы, и (б) приводят в действие установочное устройство, устанавливая первый модуль в заданное положение по радиусу относительно опорной точки, отличающееся от положения второго модуля относительно этой точки, причем скважинный прибор может работать по меньшей мере в двух положениях относительно опорной точки. 2. Способ по п.1, в котором опорная точка находится на оси ствола скважины, а заданным положением первого модуля является радиальное положение, выбираемое из практически эксцентричного и практически концентричного положений относительно оси ствола скважины. 3. Способ по п.1, в котором управление установочным устройством осуществляют посредством контроллера. 4. Способ по п.3, в котором установочным ...

Vorrichtung im Bohrloch und Verfahren zur Bestimmung der Eigenschaften einer Formation

FORMATION SAMPLING APPARATUS

Schutz für ein Bohrlochmessystem

Apparatus and method for valve actuation

Sponge pressure equalization system

Fluid flow rate analysis for wireline formation testing tools

Apparatus and method for measuring water content and salt concentration in a multiphase fluid flow

Improved flexibility of downhole fluid analyzer pump module

An apparatus, system and method for injecting a fluid into a formation downhole

Sponge pressure equalization system

Cylindrical shaped snorkel interface on evaluation probe

Downhole sampling tool and method

The invention is to allow accurate determination of a predetermined volatile gas, e.g. H2S, in a wellbore fluid. The device comprises a hollow body having an interior sampling column 16 and an exterior sample probe (36, fig 1). The fluids enter the device, are guided through conduit 22 and can pass through valve 60 to the sample column 16. Sample column 16 has inlet valve 60 and inlet filter 54 which pass into the gas extraction system 64. The gas extraction system 64 uses a binding material in the form of spherical particles to cause the volatiles to react irreversibly to produce inert or non-volatile compounds, e.g. H2S to FeS2. The binding material depends upon the predetermined gas to be measured and can be transition metals or metal oxides, either of which can be doped, organic materials such as amines, or materials of the form R1R2XYR3R4 where X and Y are carbon or nitrogen atoms and any of the two R groups contain electronegative ...

Method and apparatus for sampling formation fluids

Optical tool and method for analysis of formation fluids

A formation fluid analysis tool has a sampling probe that is inserted into the formation for extracting formation fluid and a sample chamber wherein said fluid is measured. The chamber contains an internal reflectance crystal in contact with formation fluid. An acousto-optical tunable filter (AOTF) transmits a single wavelength of light from a broadband light source. This monochromatic light is carried by an optic fiber to the internal reflectance crystal where it undergoes total reflection at the crystal faces in contact with the formation fluid. The reflected light carries information about this absorption, which is determined by the chemical composition of the fluid. A return fiber conveys the reflected light back to a spectrometer, and a processor determines the absorption at the wavelength of the monochromatic light.

Using sensors to determine the correct depth for lateral drilling

A method of determining a desirable depth for drilling a horizontal well within an oil reservoir includes the steps of deploying data sensors (120, 124, 128) at discrete depths in a subsurface formation penetrated by a wellbore (104); gathering formation pressure data for the discrete depths and determining the depth of a reservoir from the gathered data. Once the correct depth has been identified, the wellbore, or a lateral bore depending from the wellbore, can be steered into the reservoir. The sensors (124) are deployed in the formation from a drill collar (132) on a drill string (103) by a piston (328) that is exposed to hydraulic pressure which is communicated to piston chamber (332) from a hydraulic system (334).

Probe assembly for downhole formation testing

An isolator probe assembly (10), useful in formation testing equipment, has a pad comprising a primarily metallic pad member (16) and a retractable resilient sealing member. The resilient sealing member (46) is maintained in a retracted, protected position until extended to seal against the wellbore. When extended, the metallic pad pushes into the mudcake (24) until a raised ring of material on the surface of the pad contacts the formation. Once the pad is in place, the resilient sealing member, which is molded to an extending metal sleeve (18), is extended and contacts the mudcake to form a primary seal. With the primary and secondary seals energized, a fluid sample can be collected from the formation without contamination from wellbore fluids.

Methods and apparatus for the measurement of hydrogen sulphide and thiols in fluids

Formation testing using differential pressure conditions to actuate sample mechanism

A method and apparatus collects downhole data during a drilling operation via a downhole tool (100, fig 1). A differential pressure is creatd by the difference between internal pressure P1 of fluid passing through the downhole tool and the annular pressure PA in the wellbore. The apparatus includes a drill collar (130, fig 1) connectable to the downhole tool, and has an opening 380 extending into a chamber 355 therein. A piston 350 is positioned in the chamber and has a rod 370 extending into the opening. The piston is movable between a closed position, fig 3A, with the rod filling the opening, and an open position, fig 3B, with the rod retracted into the chamber to form a cavity 395 for receiving downhole fluid. The piston is moved by changes in the differential pressure between the annulus and the internal fluid passing through the tool. A sensor 360 is positioned in the rod for collecting data from fluid in the cavity. The apparatus may also be provided with a probe 410 and/or hydraulic ...

Methods to detect formation pressure

Methods for estimating formation pressure from data taken during the drawdown cycle are presented. In one aspect, a method of determining a formation pressure during drawdown of a formation comprises sampling fluid from a formation using a downhole tool having a sample volume and a fluid sampling device. At least one time despendent parameter of interest related to the fluid is determined during the drawdown. The at least one time dependent parameter is analyzed using a plurality of calculation techniques to determine the formation pressure. The techniques include (i) a first pressure derivative technique. (ii) a second pressure derivative technique. (iii) a formation rate analysis technique; (iv) a dp/dt-ratio technique, and (v) a stepwise drawdown technique.

Focused probe apparatus and method therefor

Pump control for formation testing

Formation evaluation probe set quality and data acquisition method

METHOD FOR DETERMINING HORIZONTAL AND OR VERTICAL PERMEABILITY OF A SUBSURFACE EARTH FORMATION

Downhole system and method for determining formation properties

A downhole tool (1) for taking formation fluid samples and determining formation properties is attached to a drill pipe or tubing stand (20), the tool is lowered into a borehole (13) by stands of drill pipe (20a). The wireline cable (21) can enter the pipe or tubing via a side-door sub (22) and also connects the tool to surface equipment establishing electrical communication. A probe or packer module (4) in fluid communication with the tool body engages the borehole wall (12). The borehole, downhole tool and drill pipe are all filled with drilling mud. By decreasing pressure within the tool formation fluid, both contaminated fluid (6) and less/uncontaminated reservoir fluid (7), begins to flow into the probe (4). The unwanted contaminated fluid (6) is found nearer to the borehole than the less/uncontaminated reservoir fluid (7) and is extracted first. An analyser in the tool can determine contamination levels. Unacceptable fluid (7) is pumped or flowed through the tool via a flowline (23 ...

A packer for use in a cased borehole

A system usable with a subterranean well having a casing comprises a packer (619) which is lowered downhole inside the casing, and a sensor (636) attached to the packer to measure a characteristic of the well surrounding the borehole. The packer may be mounted on a production string (626) or other tools used in a borehole and is set in place against the casing wall by expanding portions (634) of the packer. The sensor may be designed to measure through the borehole casing or puncture the casing by means of a projectile. Sensing means may measure voltage/currents, pressure, gravity, gamma rays, and NMR for example.

Downhole measurement apparatus and technique

Methods and apparatus for characterizing downhole fluids, and circulation pumps for use in such methods and apparatus

Chemical sensor for wellbore applications

Optical tool and method for analysis of formation fluids

Optical probe for analysis of formation fluids

Validating initiation of sample capture of borehole fluid

A method and apparatus for determining conditions that would render optical density measurements invalid and downhole sample capture of a borehole fluid premature. The method comprises pumping borehole fluid through an optical analyser and measuring optical density (OD) of the fluid to produce a series of OD values at intervals of time, testing for scattering within the sample, and initiating sample capture if scattering is less than a predetermined value.

A formation evaluation tool

A Formation Evaluation tool 300 positionable in a wellbore adjacent a subterranean formation F, the tool being part of a drill string positioned near the drill bit, the tool comprising a housing, a fluid inlet, a fluid pump and a plurality of sample chambers. The fluid inlet comprising a probe 211 that is extendable from the housing into communication with the formation F; and the pump 301 comprising at least one piston having a charge and a discharge stroke. The pump 301 is powered by a pressure differential between the mud pressure in a drill string and the pressure in the annulus caused when the mud is pumped through the drill bit at the bottom of the string, or through other restrictions in the drill string. Further disclosed are details of, and operating methods for, the pump.

Borehole probe assembly fitted with electrodes

A borehole formation testing system measures resistivity of near borehole formation in situ rather than the measuring the resistivity of fluid drawn into a formation tester tool. A radially extendable probe assembly 112 contacts and forms a hydraulic seal with the wall of a borehole using a pad 113. Electrode contacts 122, 124, 126 are disposed on the contact surface of the pad and electrically contact the near borehole formation. A fluid port 156 traverses the probe structure. The response of the electrode contacts are used to determine resistivity of the near borehole formation. The resistivity of the near borehole environs may be compared with an independent deep resistivity measurement to detect the presence of virgin formation in the vicinity of the pad fluid port. Alternately, a plurality of resistivity measurements is made at the formation tester pad and virgin formation fluid at or near the pad is determined from the rate of change of the plurality of resistivity measurements.

Apparatus and methods for collecting a downhole sample

Methods and apparatus for collecting a downhole sample are provided. The method may include conveying a sampling tool in a borehole using a first carrier, conveying a sample container in the borehole using a second carrier, and introducing a downhole sample from the sampling tool to the sample container. An apparatus includes a sampling tool disposed on a first carrier, a sample container disposed on a second carrier, wherein the first carrier and the second carrier are independently conveyable in a borehole, and a coupling connectable to the sampling tool and the sample container.

Method for treating and sealing piezoelectric tuning forks

Disclosed is an apparatus for estimating a property of a fluid. The apparatus includes: a piezoelectric resonator configured to be disposed in the fluid; an electrode embedded in the piezoelectric resonator and included in a resonator circuit configured to output an electrical signal related to the property; a discontinuity defined by a surface of the piezoelectric resonator, the discontinuity altering an impedance of the resonator circuit if a high-dielectric fluid or a conductive fluid is disposed in the discontinuity; and an insulating material disposed in the discontinuity.

Downhole sampling apparatus and method for using same

A downhole fluid properties analysis device and tools comprising such a device

Apparatus and method for formation evaluation

Apparatus and methods to remove impurities at a sensor in a downhole tool

Improved flexibility of downhole fluid analyzer pump module

Fluid composition and reservoir analysis using downhole gas chromatography

Methods are provided for reservoir analysis. In some embodiments, a reservoir may be analyzed by obtaining abundance ratios at a first measurement station and a second measurement station and determining an abundance ratio trend. Abundance ratios at a third measurement station may be obtained and plotted versus depth with the previously obtained abundance ratios. A change in the abundance ratio trend may be identified and result in further investigation of the reservoir. If the abundance ratio is unchanged, additional abundance ratios may be obtained and plotted versus depth to further evaluate the abundance ratio trend. Methods for reservoir analysis using fluid predictions with and without offset well information are also provided.

FORMATION-TESTING TOOL FOR OBTAINING MULTIPLE MEASUREMENTS AND FLUID SAMPLES

... 1449857 Formation sampling tool SCHLUMBERGER Ltd 7 Dec 1973 [8 Dec 1972] 56739/73 Heading E1F A formation testing tool includes a pump operable to pressurise a hydraulic circuit to successively higher pressure levels to cause sequential operation of the components of a fluid admission assembly intended to isolate an area of a wellbore wall, establish communication with a formation of interest via the isolated area and then admit a sample of concrete fluid into the tool. In a preferred embodiment, the pump 110 and its drive motor 111 are installed in an accumulator 112 including a piston 115 responsive to the ambient pressure in the well, the pump delivering into set and reset lines 119, 120 having respective solenoid-operated valves 121, 122 which together with the motor 111, a by-pass valve 127, pressure switches 124-126 and other solenoid-operated valves 182, 188 referred to below are controlled from the surface via switches (33, 34). When the tool reaches a required downhole location ...

Dual flowline testing tool with pressure self-equalizer

Flowline pressure equalizer systems, methods and/or apparatuses for use on a downhole tool are provided. A pressure equalizer may be provided in communication with two flowlines. The pressure equalizer may use equalizing chambers and equalizing pistons to regulate pressure in one or both flowlines. Further, one or more flow routing modules may be interchangeable to further alter the flow scheme between the flowlines. Different plugs may house various flow routing configurations such that the plugs may be installed and/or removed in the tool string automatically or by a user.

Apparatus and methods for estimating a characteristic of a fluid downhole using thermal properties of the fluid

Formation Testing Apparatus.

... 1,163,143. Obtaining fluid samples from mineral formations. SCHLUMBERGER TECHNOLOGY CORP. 14 Oct., 1966, No. 45916/66. Heading E1F. Apparatus for lowering down a borehole, to obtain a fluid sample from the formations traversed by the hole, comprises a seal 118, Fig. 3, engageable with the borehole wall and including a resilient annular member 124 with a rigid tubular insert 119, and a rigid compression member 128 behind member 124. Stop tube 140 is fixed to insert 119 and slides in member 128 to limit movement of member 124 into the formation of this erodes. Member 124 is pressed against the formation by borehole fluid acting in channels 132, 133, 134, 135, 135a. Body 165 forms part of a member which is lowered into the borehole and includes a hydraulic pressure system to move the body, and with it the seal, against the formation, a sample-receiving chamber, and measuring and control devices as is known in the art. Body 165 contains an explosive charge 160 which when fired ruptures cap ...

Method and apparatus for aquiring and processing subsurface samples of connate fluid

REMOTE-CONTROLLED APPARATUS

Borehole apparatus

... 904,131. Boring earth &c. SCHLUMBERGER WELL SURVEYING CORPORATION. Aug. 8, 1960 [Aug. 12, 1959], No. 27474/60. Class 85. Apparatus for sampling fluid from a formation 13 comprises a body 16, 17, 18, a seal 21 on the body surrounding the initially closed end of a conduit 65, 66, 70, 72 connected to a sample-receiving chamber 73, a device 23 on the body hydraulically operated to press the seal against the formation, a perforator 59 for opening the conduit to fluid from the formation, pressure-measuring means 68 in the part 66 of the conduit, and a valve 67 to close the conduit between the parts 70, 72. When the apparatus is positioned with the seals 21, 22 opposite the formation a valve 51 is opened to permit bore fluid 15 to flow through aperture 52 to pressure means 30 which supplies amplified pressure to cylinder 33 so that the device 23 engages to formation and presses the seals against the formation. Shaped changes 59, 60 are detonated, and formation fluid flows through conduit parts ...

Methods and apparatus for analyzing a downhole fluid

Down hole tool for determination of formation properties.

Formation sampling apparatus.

Wellbore logging system.

PROCEDURE AND DEVICE FOR THE ANALYSIS OF THE BOREHOLE LIQUID

DEVICE IN THE BOREHOLE AND PROCEDURE FOR THE DETERMINATION OF THE CHARACTERISTICS OF A FORMATION

TOOL FOR THE INVESTIGATION OF LAYERS.

PROCEDURE FOR THE DETERMINATION OF A LIQUID CONTACT LEVEL IN A FORMATION

Systems and methods for generating permeability scaling functions to estimate permeability

Systems and methods for generating permeability scaling function for different features of interest are disclosed. Exemplary implementations may: obtain subsurface data sets; generate permeability scaling functions for individual features of interest; store the permeability scaling functions; and generate upscaled subsurface distributions using the permeability scaling functions.

Downhole sampling apparatus and method for using same

Systems and methods of a clamp for a sample bottle assembly

Clamp for a sample bottle assembly. At least some of the illustrative embodiments are apparatuses including a first drill collar section. The first drill collar includes: a first outer surface; a pocket accessible through an aperture in the first outer surface; a bottle assembly disposed within the pocket; and an intermediate clamp coupled to the first outer surface and spanning the pocket, the intermediate clamp at least partially retains the bottle assembly in the pocket, and the intermediate clamp has an axial length less than an axial length of the bottle assembly.

Equalizer valve and associated method for sealing a fluid flow

Valve shift detection systems and methods

The present disclosure relates to valve systems that include valve shift detection systems that can be employed to determine when a valve has shifted. According to certain embodiments, the valve shift detection systems may include a switch integrated into a valve block that may be closed upon shifting of the spool valve. In certain embodiments, the switch may include a component that completes a circuit upon contacting the valve. The valve shift detection systems also may include a controller designed to detect a voltage or current change produced by completing the circuit.

Controlling formation tester probe extension force

A formation tester for use in a subterranean well can include a probe which extends outward into contact with an earth formation, and an adjustable flow control device which limits an extension pressure applied to extend the probe. A method of testing a subterranean formation can include positioning a formation tester in a wellbore, extending a probe of the formation tester outward into contact with the formation, and limiting a force applied by the probe to the formation, the limiting being performed by variable actuation of a flow control device downhole. Another formation tester can include a probe which extends outward into contact with an earth formation, with a force applied by the probe to the formation being remotely adjustable downhole.

System and method for collecting a representative formation fluid during downhole testing operations

A method for collecting a formation fluid for testing includes introducing a formation sample tool having a first port and a second port into a wellbore. A first fluid is injected through the first port into the formation to clear a sample passage and allow access to uncontaminated formation fluid. A second fluid is injected through the second port into the formation to provide a barrier adjacent to or around the sample passage. A sample of the uncontaminated formation fluid is removed from the formation through the first port.

System and method for estimating oil formation volume factor downhole

A system includes a downhole formation fluid sampling tool and a processor. An optical spectrometer of the downhole formation fluid sampling tool is able to measure an optical characteristic of a formation fluid flowing through the downhole formation fluid sampling tool over a plurality of wavelengths. The optical spectrometer generates optical spectra data indicative of this optical characteristic. The processor is designed to receive the optical spectra data generated by the optical spectrometer and to estimate a formation volume factor of the formation fluid based on the optical spectra data.

Reservoir management system and method

Equi-pressure geosteering

Formation pressure measurement with remote sensors in cased hole

Reservoir management system and method

METHODS AND APPARATUS TO SAMPLE HEAVY OIL IN A SUBTERRANEAN FORMATION

METHODS FOR MEASURING A FORMATION SUPERCHARGE PRESSURE

A method of determining the supercharge pressure in a formation intersected by a borehole having a wall, the method comprising disposing a formation pressure test tool into the borehole having a probe for isolating a portion of the borehole. The method further comprises extending the probe into sealing contact with the borehole wall. The method further comprises performing at least one drawdown test with the formation pressure test tool. The method further comprises modeling the supercharge pressure of the formation using the dynamic properties of the mudcake. The method further comprises determining the supercharge pressure of the formation using the supercharge pressure model. The formation pressure test tool may be conveyed into the borehole using wireline technology or on a drill string. Using the supercharge pressure, the drawdown test may be optimized, the characteristics of the drilling fluid altered, or the measurements of other sensors adjusted.

PUSH-OFF PISTONS

METHODS AND APPARATUS FOR THE DOWNHOLE CHARACTERIZATION OF FORMATION FLUIDS

Methods and apparatus for investigating a hydrocarbon bearing geological formation traversed by a borehole are disclosed. An example method to characterize a fluid associated with an underground geological formation obtains a sample of the fluid associated with the underground geological formation. The example method measures, in a borehole associated with the underground geological formation, a chemical composition and a thermophysical property of the sample of the fluid. The example method selects a mathematical model to represent the sample of the fluid based on at least one of the chemical composition or the thermophysical property and adjusts a parameter of the mathematical model based on at least one of the chemical composition or the thermophysical property to generate an adjusted mathematical model. The example method then determines a property of the fluid associated with the underground geological formation based on the adjusted mathematical model.

METHOD FOR FAST AND EXTENSIVE FORMATION EVALUATION

A minimum volume apparatus and method is provided including a tool for obtaining at least one parmeter of interest of a subterranean formation in- situ, the tool comprising a carrier member, a selectively extendable member mounted on the carrier for isolating a portion of annulus, a port exposable to formation fluid in the isolated annulus space, a piston integrally disposed within the extendable member for urging the fluid into the port, and a sensor operatively associated with the port for detecting at least one parameter of interest of the fluid.

APPARATUS AND METHODS TO PERFORM OPERATIONS IN A WELLBORE USING DOWNHOLE TOOLS HAVING MOVABLE SECTIONS

Apparatus and methods to perform operations in a wellbore using down-hole tools having movable sections are described. In one described example, a downhole tool for use in a wellbore includes a first extendable anchor to contact a wall of the well-bore to fix the tool at a location in the wellbore. The downhole tool also includes a first tool of the downhole tool to perform a first operation at the location in the wellbore, and a second tool of the downhole tool spaced from the first tool and to perform a second operation. Additionally, the downhole tool includes an extendable member to move the second tool to the location while the anchor is in contact with the wall of the wellbore to perform the second operation after the first operation.

FORMATION SAMPLER WITH CLEANING CAPABILITY

Sampling tools are used to extract samples of underground reservoir fluids. The extracted samples can either be analyzed down-hole or stored in a container for subsequent laboratory analyses. In either case, the fluid sample must be representative of both the chemical composition and physical properties of the formation fluid about the volume of sampling acquisition. Often, one sampling tool is used to acquire fluids from several locations within a reservoir. It is highly likely that fluid sampled at a first location in the reservoir may have adhered to the inner walls of the flow line or other hydraulic components of the sampling tool. Consequently, fluid extracted from a second location within the same reservoir may be contaminated by that remaining from the first acquisition. As a consequence, the chemical composition and physical properties determined by analyses of the second fluid may not actually be of the formation fluid but of a mixture of the first and second fluid and thus be ...

METHODS AND APPARATUS FOR DOWNHOLE CHARACTERIZATION OF EMULSION STABILITY

A method (and corresponding apparatus) for downhole fluid analysis of petroleum formation fluids. The method includes capturing in a chamber (30) of a downhole tool (10) at least two immiscible formation fluids in a generally segregated state (the fluids including petroleum), activating a fluid mixing means (62) to mix the fluids in the chamber to create an emulsion therefrom, and allowing the emulsified fluids to segregate while measuring light transmittance through the segregating fluids in order to calculate a transition time period based on the light transmittance through the fluids in the chamber. The transition time period is preferably bounded by the time required for the light transmittance values measured by the light detector to reach a baseline light transmittance. The transition time period characterizes the stability of an emulsion formed by the captured fluids.

SINGLE PACKER STRUCTURE WITH SENSORS

A technique involves collecting formation fluids through a single packer (24) having at least one drain located within the single packer. The single packer is designed with an outer flexible skin (26) and one or more drains (30) coupled to the outer flexible skin. The single packer further comprises one or more sensors (42, 48) positioned to detect one or more specific parameters that may be related to well characteristics and/or single packer characteristics.

APPARATUS FOR TESTING EARTH FORMATIONS

APPARATUS FOR TESTING EARTHFORMATIONS Apparatus is provided for collecting a plurality of samples of fluids in earth formations traversed by a well bore. The sampling apparatus includes an elongated body member adapted to carry an extensible and retractible fluid admitting probe which is selectively placed in sealing engagement with potentially producible earth formations. The fluid admitting probe is coupled to a fluid passage which is selectively placed into fluid communication with a fluid sample collection chamber. A pressure control assembly located in the fluid passage intermediate the fluid admitting probe and the sample collection chamber maintains the pressure within at least a portion the fluid passage of a predetermined proportional minimum level of formation pressure during fluid sample collection.

METHOD FOR FAST AND EXTENSIVE FORMATION EVALUATION

A minimum volume apparatus and method is provided including a tool for obtaining at least one parmeter of interest of a subterranean formation in- situ, the tool comprising a carrier member, a selectively extendable member mounted on the carrier for isolating a portion of annulus, a port exposable to formation fluid in the isolated annulus space, a piston integrally disposed within the extendable member for urging the fluid into the port, and a sensor operatively associated with the port for detecting at least one parameter of interest of the fluid.

APPARATUS AND METHOD FOR CHARACTERIZING A RESERVOIR

An apparatus and method for characterizing a subsurface formation is provided. The apparatus includes a tool body, a probe assembly carried by the tool body for sealing off a region of the borehole wall, an actuator for moving the probe assembly between a retracted position for conveyance of the tool body and a deployed position for sealing off a region of the borehole wall and a perforator extending through the probe assembly for penetrating a portion of the sealed-off region of the borehole wall. The tool may be provided with first and second drilling shafts with bits for penetrating various surfaces. The method involves sealing off a region of a wall of an open borehole penetrating the formation, creating a perforation through a portion of the sealed-off region of the borehole wall and testing the formation.

METHOD AND APPARATUS FOR DETERMINING DOWNHOLE PRESSURES DURING A DRILLING OPERATION

A method and apparatus is provided to collect downhole data during a drilling operation via a downhole tool. A differential pressure is created by the difference between internal pressure of fluid passing through the downhole tool and the annular pressure in the wellbore. The apparatus includes a drill collar connectable to the downhole drilling, and has an opening extending into a chamber therein. A piston is positioned in the chamber and has a rod extending into the opening. The piston is movable between a closed position with the rod filling the opening, and an open position with the rod retracted into the chamber to form a cavity for receiving downhole fluid. A sensor is positioned in the rod for collecting data from fluid in the cavity. The apparatus may also be provided with a probe and/or hydraulic circuitry to facilitate the collection of data.

SUB APPARATUS WITH EXCHANGEABLE MODULES

The present invention is an apparatus and method for use in a well borehole drilled into a formation. The apparatus comprises a work string disposed in the borehole. The work string includes at least one modular body portion having at least one receptacle. A modular tool is disposed in the at least one receptacle for carrying out a drilling operation. The modular tool may be a tool for use in drilling a well borehole, it may be a tool for testing a formation surrounding a borehole, or the modular tool may be a combination. For example, one aspect of the present invention provides a modular steering rib. The modular steering rib may also include modular components for sampling and testing formation fluid.

UNDERGROUND TOOL FOR THE IN-SITU ASSESSMENT OF AQUIFER QUALITY AND FLOW RATE

An underground sampling tool (HTMS) for underground water analysis of both quality and flow rate, providing the information required to perform an underground drilling and obtain uncontaminated water for crop irrigation, said tool comprising: a housing for the electronic and electrical controls, a housing for the hydraulic means controlled by the electric and electronic portion of the tool, a test body consisting of a variety of hydraulic circuits for operating the various operating valves of the tool, wherein said test body further comprises: a rear shoe on an axial axis of the tool, wherein said rear shoe is driven by two telescoping pistons simultaneously that arise from the inside of the tool when driven by a signal of a surface equipment operably enabled for this purpose, and a front shoe, driven by several pistons which are housed below the front shoe, not shown in the figures, and driven by one or more electro-pneumatic devices acting jointly and generating a progressive forward ...

ACOUSTIC TESTING OF CORE SAMPLES

A central member defines a sample chamber and includes an elastic material configured to enclose at least a portion of a sample, acoustic sensors configured to detect sound waves in the sample chamber, and acoustic emitters configured to emit sounds waves in the central member. A pressure-retaining case is configured to contain a pressurized fluid between an annulus formed between the pressure-retaining case and the central member. A switch is configured to connect or disconnect a pulser and receiver circuit to a specified emitter of the acoustic emitters. A data acquisition unit is configured to receive a signal from each of the acoustic sensors. A pulser and receiver circuit is configured to send an electric pulse to an acoustic emitter and a control signal to the data acquisition unit.

METHOD AND APPARATUS FOR SUB-TERRAIN CHLORINE ION DETECTION IN THE NEAR WELLBORE REGION IN AN OPEN-HOLE WELL

Methods and systems for identifying a salinity gradient in a formation surrounding a bore of a subterranean well includes introducing an antenna assembly into the bore of the subterranean well. The antenna assembly has an elongated antenna body. An emitting antenna extends axially along an outer surface of the antenna body. A receiving antenna extends axially along the outer surface of the antenna body, the receiving antenna being spaced circumferentially apart from the emitting antenna. An electromagnetic interrogation wave is produced into the formation with the emitting antenna with a pulse duration of no greater than 0.01 seconds. A reflected wave is received with the receiving antenna. The amplitude of the reflected wave is analyzed to determine a distribution of chlorine ion concentration in the formation.

APPARATUS AND METHOD FOR SYNCHRONIZED FORMATION MEASUREMENT

The present invention provides an apparatus and method for minimizing movement of a drill string during MWD with vibration-sensitive instruments comprising conveying a drill string into a borehole with a sensor mounted on the drill string for sensing a parameter of interest of a formation. A clocked controller is disposed on the drill string for controlling timing of the sensor; and a second clocked controller is disposed at a surface location. During drilling operations, the clocked controllers are synchronized such that the surface controller is performing certain tasks in timed sequence with the sensor, even though the surface controller is not connected to the sensor. The instruments may contain an NMR sensor or an extendable probe conencting a sample chamber via a probe.

Valve assembly employable with a downhole tool

A valve assembly employable with a downhole tool configured for conveyance in a wellbore extending into a subterranean formation and method of operating the same. In one embodiment, the valve assembly includes an actuator and a sensing apparatus configured to provide a first signal based on an environment associated with the valve assembly and a second signal based on a characteristic of the valve assembly. The valve assembly also includes a controller configured to provide a third signal to the actuator to alter the characteristic in response to the first and second signals.

Fluid control in reservior fluid sampling tools

A pumping system comprising: a probe to suction a fluid from a fluid reservoir; a pump in fluid communication with said probe; a sensor for detecting phase changes in said pumping system, said sensor in fluid communication with said probe or pump, said sensor generating a sensor signal; a fluid exit from said pumping system, said fluid exit being in fluid communication with said pump; and a variable force check valve located between said probe and said fluid exit.

Downhole sample analysis method

A method for downhole fluid analysis is disclosed. The method includes positioning a downhole fluid sampling tool at first and second locations; extracting and compositionally analyzing samples of reservoir fluid while positioned at the first and second locations; comparing analysis results; and repositioning the tool to a third location depending on the results of the comparison. The compositional analysis can be performed using downhole gas chromatography and mass spectrometry systems and preferably can identify subtle non-homogeneities such as biomarkers. The fluid extraction can be performed using a focuses dual-flowline type sampling probe.

System and method for sampling and analyzing downhole formation fluids

A device for sampling fluid from an earth formation is disclosed. The device includes: an inlet port disposable in fluid communication with the fluid in a borehole; an injector including an injection chamber in fluid communication with the inlet port, the injector configured to receive a portion of the fluid and direct the fluid toward an analysis unit for analyzing constituent materials in the fluid; and a high pressure valve configured to admit the portion of the fluid at a borehole pressure and release the portion of the fluid into the injector, the portion having a volume that is less than or equal to about one microliter. A system and method for analyzing constituents of fluid in a borehole in an earth formation is also disclosed.

Methods and devices for filling tanks with no backflow from the borehole exit

A method for sampling fluid from a subsurface formation includes retrieving fluids from the formation using a plurality of pumps, controlling a flow of the retrieved fluids using at least a first valve and a second valve, estimating an operating parameter of at least one pump of the plurality of pumps, and controlling the first valve and the second valve using the estimated operating parameter to initiate a fluid sampling event.

Downhole mixing device for mixing a first fluid with a second fluid

Methods and devices for mixing a first fluid with a second fluid downhole include a chamber having a first end, a second end and an opening for fluid to flow there through. A top surface of a perforated piston is capable of contacting the second end and a top surface of a piston is capable of contacting a bottom surface of the perforated piston. The perforated piston is located at a first position within the chamber based upon characteristics of a first fluid. A first fluid delivery system supplies the first fluid and a second fluid delivery system supplies a second fluid to the chamber, wherein the second fluid is at a pressure that moves the piston approximate to the first end. An actuating device applies a force against the bottom surface of the piston to inject the fluids through channels of the perforated piston to produce spray droplets.

Systems and methods of a sample bottle assembly

A sample bottle assembly. At least some of the illustrative embodiments are apparatuses including a first drill collar that includes: a first outer surface; a pocket accessible through an aperture in the first outer surface; a bottle assembly disposed within the pocket; a first end-clamp coupled within a first recess disposed at an upper end of the pocket to at least partially retain the bottle assembly in the pocket; and a second end-clamp coupled within a second recess disposed at the lower end of the pocket to at least partially retain the bottle assembly in the pocket. The bottle assembly further includes: a sample bottle having an axial length; and a sleeve comprising a bore, the sample bottle received within the bore, and the sleeve has an axial length substantially the same as the sample bottle.

Determination Of Thermodynamic Properties Of A Fluid Based On Density And Sound Speed

Variable volume systems and methods of use thereof described herein are capable of making calibrated determinations of fluid properties and phase behavior of a fluid sample. The determinations can be calibrated based on one or more calibration functions, such as system volume corrected for pressure and temperature variations. Cross-checking the results of measurements can be used to determine accuracy of the calibration or monitor for leaks or other anomalies of the variable volume systems. The variable volume systems can be implemented in a well logging tool and are capable of being calibrated downhole.

Downhole Fluid Filter

An apparatus for testing a subterranean formation penetrated by a wellbore, comprising a tool having a sample flow line an inlet disposed with the tool and configured to establish fluid communication between the formation and the sample flow line to draw a fluid sample into the sample flow line, and an active filter positioned in the sample flow line and providing a filter flow route and a bypass flow route in the sample flow line.

Downhole Formation Tester Apparatus And Methods

A method according to one or more aspects of the present disclosure includes moving a piston of a displacement unit to pump a fluid through first and second flowlines hydraulically connected to the displacement unit through a valve network. The method also includes monitoring flowing pressure in the first flowline and monitoring pressure in a first chamber of the displacement unit. The method further includes opening a first active valve of the valve network in response to the monitored pressure in the first chamber being about equal to or less than the monitored flowing pressure in the first flowline. 1. A system , comprising:a displacement unit configured to pump fluid;a first flowline hydraulically connected to the displacement unit through a valve network for selectively communicating the fluid to or from the displacement unit;a second flowline hydraulically connected to the displacement unit through the valve network for selectively communicating the fluid to or from the displacement unit;a first chamber pressure gauge hydraulically coupled with a first chamber of the displacement unit;a second chamber pressure gauge hydraulically coupled with a second chamber of the displacement unit; a power supply providing a force configured to operate the displacement unit;a force sensor configured to measure the force;a sample probe hydraulically coupled to the first flowline;a first flowline pressure gauge hydraulically coupled to the first flowline between the sample probe and the valve network; anda fluid sample chamber hydraulically coupled to the second flowline.2. The system of claim 1 , wherein the power supply comprises a hydraulic pump.3. The system of claim 1 , wherein the power supply comprises a motor driving a mechanical shaft.4. The system of claim 1 , wherein the force sensor comprises a differential pressure gauge.5. The system of claim 1 , wherein the force sensor is configured to measure motor torque.6. The system of claim 1 , wherein the force sensor is ...

Methods And Apparatus To Sample Heavy Oil In A Subterranean Formation

A method for sampling fluid in a subterranean formation includes, reducing a viscosity a fluid, pressurizing a portion of the subterranean formation, and collecting a fluid sample. Specifically, a viscosity of a fluid in a portion of the subterranean formation is reduced and a portion of the subterranean formation is pressurizing by injecting a displacement fluid into the subterranean formation. A sample of the fluid pressurized by the displacement fluid is then collected.

Downhole Tools and Oil Field Tubulars having Internal Sensors for Wireless External Communication

A downhole tool has a housing assembly with an interior and an exterior. A sensor is disposed to the interior of the housing assembly. The sensor is operable to obtain data relative to a fluid parameter of a fluid disposed within the interior of the housing assembly and operable to wirelessly transmit the data to a data acquisition device disposed to the exterior of the housing assembly responsive to interrogation by the data acquisition device. 1. A downhole tool comprising:a housing assembly having an interior and an exterior; anda sensor disposed to the interior of the housing assembly, the sensor operable to obtain data relative to a fluid parameter of a fluid disposed within the interior of the housing assembly and operable to wirelessly transmit the data to a data acquisition device disposed to the exterior of the housing assembly responsive to interrogation by the data acquisition device.2. The downhole tool as recited in wherein the interior of the housing assembly further comprises a fluid chamber of a downhole tester valve and wherein the sensor is disposed within the fluid chamber.3. The downhole tool as recited in wherein the downhole tester valve further comprises:a mandrel assembly disposed within the housing assembly defining therebetween an operating fluid chamber, a biasing fluid chamber and a power fluid chamber;a valve assembly disposed within the housing assembly operable between open and closed positions; anda piston assembly operably associated with the valve assembly;wherein, the sensor is disposed within at least one of the operating fluid chamber, the biasing fluid chamber and the power fluid chamber.4. The downhole tool as recited in wherein the interior of the housing assembly further comprises a sampling chamber of a fluid sampler and wherein the sensor is disposed relative to the sampling chamber.5. The downhole tool as recited in wherein the fluid sampler further comprises:an actuator operable to establish a fluid communication path ...

Flexibility of downhole fluid analyzer pump module

An apparatus for pumping a downhole fluid includes: a carrier configured to be conveyed through a borehole penetrating the earth; a pump disposed at the carrier and configured to pump the downhole fluid; a multi-phase electric motor coupled to the pump and configured to receive multi-phase electrical energy from a power source in order to operate the pump, the multi-phase electrical motor having multiple windings; and a switch configured to connect the multiple windings in a configuration selected from a plurality of configurations that includes (i) a first configuration where one terminal of each winding of the multiple windings is uniquely connected to one terminal of another winding and (ii) a second configuration where one terminal of each winding of the multiple windings is commonly connected to one terminal of each of the other windings.

Packer Assembly With Sealing Bodies

A packer assembly has an inner expandable packer. An outer layer having sealing bodies may be disposed about and/or positioned on the outer surface of the inner expandable packer member. Each of the sealing bodies may have an elastomeric body, and one or more flowlines may be embedded in the elastomeric body of each of the sealing bodies. The sealing bodies may be located in grooves in the inner expendable packer member. The sealing bodies may contact a surrounding casing or a surrounding formation to form an annular seal; in an embodiment, the sealing bodies and the inner expandable packer member may contact a surrounding casing or a surrounding formation to form an annular seal. The sealing bodies may be non-integral with each other and/or separable from each other. 1. A packer assembly comprising:an expandable inner packer member having an outer surface; anda first sealing body positioned external to and non-integral with the expandable inner packer member, the first sealing body having an axial length and at least one sampling port providing fluid communication to the packer assembly wherein the first sealing body is movable from a retracted position radially outward to an expanded position as the expandable inner packer member moves radially outward.2. The packer assembly of wherein the expandable inner packer member comprises an inflatable bladder that radially expands upon receipt of a predetermined amount of fluid.3. The packer assembly of further comprising a second sealing body non-integral with the expandable inner packer member and the first sealing body.4. The packer assembly of wherein the first sealing body and the second sealing body are separated by a radial distance at the expanded position.5. The packer assembly of wherein the second sealing body has a sampling port located at a different axial position than the at least one sampling port of the first sealing body.6. The packer assembly of wherein the first sealing body is made of an elastomeric ...

METHOD AND TOOL FOR EVALUATING A GEOLOGICAL FORMATION

A method of evaluating a geological formation () of non-homogeneous porosity and permeability, particularly in exploration for hydrocarbon fluids, comprising the steps of: 117-. (canceled)18. A method of evaluating a geological formation of non-homogeneous porosity and permeability comprising the steps of:(a) inserting a formation evaluation tool into a borehole by wireline, after drilling of the borehole, to a location within the geological formation;(b) setting the formation evaluation tool into position isolating interval(s) of the borehole with a packer arrangement forming portion of the formation evaluation tool, for sample evaluation for said interval(s);(c) extracting representative samples of formation fluid from the location within the geological formation for evaluation under downhole conditions using sampling means for extracting formation fluid samples over a range of porosity and permeability encountered within the geological formation; and(d) analysing the formation fluid samples and measuring formation permeability, wherein said packer arrangement is a dual or straddle packer arrangement comprising a plurality of spaced apart packers, each packer comprising sealing elements for isolating sampling interval(s) within said borehole enabling extraction of samples for acquisition of data for formation evaluation through at least one sampling port located between said sealing elements of a packer.19. A method of wherein said geological formation includes a feature selected from the group consisting of vugs claim 18 , fractures claim 18 , variable diameter pores and moldic pores.20. A method of wherein the sampling port is set back from a wall of the borehole such that a space enabling sample draw down is disposed between said sealing elements isolating a sampling interval.21. A method of wherein said data is used to evaluate vertical continuity of said geological formation.22. A method of wherein measuring differential pressure between packers spaced a ...

HEAVY OIL SAMPLING METHODS AND SYSTEMS

The present disclosure relates to a formation sampling method that includes disposing a downhole tool that has an expandable packer and an extendable probe within a wellbore disposed in a subterranean formation, pumping formation fluid into the downhole tool through the extendable probe to move heavy oil from within the subterranean formation towards the wellbore, detecting arrival of the heavy oil at the wellbore, and performing formation sampling with the expandable packer in response to detecting the arrival of the heavy oil at the wellbore. 1. A formation sampling method comprising:disposing a downhole tool comprising an expandable packer and an extendable probe within a wellbore disposed in a subterranean formation;pumping formation fluid into the downhole tool through the extendable probe to move heavy oil from within the subterranean formation towards the wellbore;detecting arrival of the heavy oil at the wellbore; andperforming formation sampling with the expandable packer in response to detecting the arrival of the heavy oil at the wellbore.2. The formation sampling method of claim 1 , wherein comprising confirming a presence of mobile heavy oil within the subterranean formation prior to disposing the downhole tool within the wellbore.3. The formation sampling method of claim 2 , wherein confirming the presence of mobile heavy oil comprises performing a combination of NMR scanning and dielectric scanning.4. The formation sampling method of claim 2 , wherein disposing the downhole tool within the wellbore comprises conveying the downhole tool within the wellbore to dispose the extendable probe at a location in the wellbore corresponding to the presence of mobile heavy oil.5. The formation sampling method of claim 1 , comprising monitoring properties of the formation fluid within the downhole tool while pumping the formation fluid into the downhole tool through the extendable probe.6. The formation sampling method of claim 5 , wherein monitoring properties of ...

SYSTEM AND METHODS FOR PRETESTS FOR DOWNHOLE FLUIDS

A method including positioning a downhole acquisition tool in a wellbore in a geological formation; performing a pretest sequence to gather at least one of pressure or mobility information based on downhole acquisition from a sample line, a guard line, or both while the downhole acquisition tool is within the wellbore. The pretest sequence includes controlling a valve assembly to a first valve configuration that may allow the fluid to flow into the downhole tool via one or more flowlines toward a pretest system. The one or more flowlines include the sample line only, the guard line only, or both the sample line and the guard line; and drawing in the fluid through the one or more flowlines. The method also includes controlling the valve assembly to a second valve configuration. The second valve configuration is different from the first valve configuration and may block the one or more flowlines from drawing in the fluid. 1. A method comprising:positioning a downhole acquisition tool in a wellbore in a geological formation; controlling a valve assembly to a first valve configuration that enables the fluid to flow into the downhole tool via one or more flowlines toward a pretest system, wherein the one or more flowlines comprises the sample line only, the guard line only, or both the sample line and the guard line; and drawing in the fluid through the one or more flowlines; and', 'controlling the valve assembly to a second valve configuration, wherein the second valve configuration is different from the first valve configuration and is configured to block the one or more flowlines from drawing in the fluid., 'performing a pretest sequence to gather at least one of pressure or mobility information based on downhole acquisition from a sample line, a guard line, or both while the downhole acquisition tool is within the wellbore, wherein the pretest sequence comprises2. The method of claim 1 , wherein drawing in the fluid comprises using a pump to draw in the fluid.3. The ...

SAMPLE PHASE QUALITY CONTROL

Systems and methods for subterranean formation testing. A method may include: lowering a formation testing tool into a subterranean formation, wherein the formation testing tool may include memory, a pump, a formation probe, at least two sample chambers, wherein the at least two sample chambers may include probes to measure pressure and temperature; extracting a fluid from the subterranean formation with the pump and the formation probe; flowing the fluid into the at least two sample chambers with the pump; storing pressure and temperature data of the fluid in the memory; and removing the at least two sample chambers from the formation testing tool. 1. A method comprising:lowering a formation testing tool into a subterranean formation, wherein the formation testing tool comprises memory, a pump, a formation probe, at least two sample chambers, wherein the at least two sample chambers comprise probes to measure pressure and temperature;extracting a fluid from the subterranean formation with the pump and the formation probe;flowing the fluid into the at least two sample chambers with the pump;storing pressure and temperature data of the fluid in the memory; andremoving the at least two sample chambers from the formation testing tool.2. The method of claim 1 , wherein the at least two sample chambers comprise a cushioned sample chamber comprising a nitrogen section and a fluid sample section claim 1 , and an un-cushioned sample chamber comprising a fluid sample section.3. The method of claim 2 , further comprising continuously monitoring pressure and temperature of the fluid within the un-cushioned sample chamber and the cushioned sample chamber from a time of recovery of the fluid to a time of opening the un-cushioned sample chamber and the cushioned sample chamber.4. The method of claim 1 , wherein the memory comprises volatile memory or non-volatile memory.5. The method of claim 1 , wherein the probes comprise feed through wires configured to allow communication and ...

APPARATUS AND METHODS FOR TOOLS FOR COLLECTING HIGH QUALITY RESERVOIR SAMPLES

Methods and systems for collecting high quality reservoir samples and determining producibility of those samples are disclosed that provide for a non-stop and no shock sampling process. The systems and methods of the present disclosure are especially important collecting samples of reservoir samples in a manner that most closely resembles production fluids and maintains the reservoir at or near the draw down pressure during the pumping and sampling processes. 1. A tool configured to sample a formation fluid from a reservoir comprising:a reservoir flowline configured to be in fluid communication with a portion of the reservoir;a main pump in fluid communication with the reservoir flowline;a sample container in fluid communication with the reservoir flowline;a sampling pump hydraulically coupled to the sample container and configured to transfer a buffer fluid in and out of the sample container; anda power and processing unit configured to control the main pump and the sampling pump to maintain the reservoir approximately at a drawdown pressure.2. The tool of claim 1 , wherein the sample container comprises:a housing having at least two pistons slidably disposed therein and dividing the housing into at least three chambers, each of the at least three chambers having a variable volume, including an intermediate chamber, a first end chamber and a second end chamber, the intermediate chamber defined by the pistons and wherein the pistons are free of valves;a first conduit configured to pressurize the intermediate chamber with a gas;a second conduit coupled to the first end chamber and the reservoir flowline; anda third conduit coupled to the second end chamber and the sampling pump.3. The tool of claim 2 , further comprising a packer claim 2 , the packer comprised of one of a donut packer and a straddle packer.4. The tool of further comprising a probe assembly claim 2 , the probe assembly comprising: a snorkel coupled to the reservoir flowline and configured to penetrate ...

DRILL STEM TESTING

Systems and techniques for determining properties of a formation comprising are disclosed. A test tool attached to test string comprising a fluid conduit is deployed to a test position within a wellbore. The deployment includes hydraulically isolating a portion of the wellbore proximate the test tool to form an isolation zone containing the test position. A fluid inflow test is performed within the isolation zone and an initial formation property and a fluid property are determined based on the fluid inflow test. A fluid injection test is performed within the isolation zone including applying an injection fluid through the test string into the isolation zone, wherein the flow rate or pressure of the injection fluid application is determined based, at least in part, on the at least one of the formation property and fluid property, The fluid injection test further includes measuring pressure within the isolation zone to determine a pressure transient associated with the injection of the injection fluid. A property of the formation is determined based on the determined pressure transient. 1. A method for determining properties of a formation comprising:performing a fluid inflow test within an isolation zone of a wellbore;determining a first formation property based, at least in part, on the fluid inflow test; and applying an injection fluid into the isolation zone, wherein a flow parameter for the injection fluid application is determined based, at least in part, on the first formation property; and', 'measuring pressure within the isolation zone to determine a pressure transient associated with the application of the injection fluid., 'performing a fluid injection test within the isolation zone including2. The method of claim 1 , further comprising determining a second formation property based on the determined pressure transient.3. The method of claim 2 , wherein said determining a second formation property comprises determining at least one of a formation flow ...

USING SCREENED PADS TO FILTER UNCONSOLIDATED FORMATION SAMPLES

A fluid-sampling system that includes a downhole tool string with a fluid-sampling tool coupled thereto, and a fluid sampling probe coupled to the tool via a probe extension arm, the fluid sampling probe having an oval pad that contacts a borehole wall, one or more fluid inlets which receive a formation fluid, and a plurality of screens between the borehole wall and the one or more fluid inlets which filter the formation fluid. The fluid-sampling system further including one or more offset arms coupled to the tool which contact the borehole wall. 1. A fluid-sampling system , comprising:a downhole tool string with a fluid-sampling tool coupled thereto;a fluid sampling probe coupled to the tool via a probe extension arm, the fluid sampling probe having an oval pad that contacts a borehole wall, one or more fluid inlets which receive a formation fluid, and a plurality of screens between the borehole wall and the one or more fluid inlets which filter the formation fluid; andone or more offset arms coupled to the tool which contact the borehole wall.2. The fluid-sampling system of claim 1 , wherein the downhole tool string further comprises a downhole pump which draws the formation fluid from the formation via the one or more fluid inlets.3. The fluid-sampling system of claim 1 , wherein the downhole tool string further comprises a fluid analyzer which receives and analyzes the formation fluid via the one or more fluid inlets.4. The fluid-sampling system of claim 1 , wherein the downhole tool string further comprises a fluid storage chamber which receives and stores the formation fluid via the one or more fluid inlets.5. A method of sampling a formation fluid claim 1 , comprising:deploying a fluid sampling tool having a fluid-sampling probe downhole;pressing an oval pad of the fluid-sampling probe against a borehole wall;drawing a formation fluid from a formation with one or more inlets of the fluid-sampling probe; andfiltering particulates from the formation fluid with ...

Tar Mat Formation Prediction in Late-Charge Reservoirs

A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time.

Pressurized Chamber Management

Apparatus and methods for filling a pressure compensated fluid container with a liquid. An example method includes restraining movement of a piston slidably disposed within the fluid container in a first piston position, wherein the piston divides the fluid container into first and second portions. The method further includes pumping the liquid into the first portion to compress gas located within the first portion, stopping the pumping of the liquid into the first portion, and stopping the restraining of movement of the piston to permit the piston to move to a second piston position due to expansion of the gas compressed within the first portion. 1. An apparatus comprising: a chamber comprising a port; and', maintain the piston in a first piston position within the chamber while the first portion receives a liquid via the port to compress gas located within the first portion; and', 'permit the piston to move to a second piston position due to expansion of the gas compressed within the first portion., 'a piston slidably disposed within the chamber and dividing the chamber into first and second portions, wherein the first portion is fluidly connected with the port and the second portion is in fluid communication with a space external to the apparatus, and wherein during liquid filling operations the apparatus is operable to], 'a pressure compensated fluid containment system comprising2. The apparatus of wherein the port is a first port claim 1 , wherein the chamber further comprises a second port fluidly connected with the first portion claim 1 , and wherein during the liquid filling operations the apparatus is further operable introduce the liquid into the first portion via the first port and discharge the liquid from the first portion via the second port to flush out the gas located within the first portion.3. The apparatus of wherein the first piston position within the chamber is selectable based at least partially on a coefficient of compression of the liquid ...

METHOD AND APPARATUS FOR FORMATION TESTING AND SAMPLING WHEN PERFORMING SUBTERRANEAN OPERATIONS

Methods and systems for improving operations of a formation tester are disclosed. The formation tester () is placed in a wellbore at a location of interest. The formation tester comprises a first isolation pad () coupled to a pad carrier () and a second isolation pad (). The first isolation is extendable to substantially seal a probe of the formation tester against a well bore wall. The first isolation pad is then replaced with the second isolation pad if it is determined that the first isolation pad should be replaced with the second isolation pad. 1. A formation tester tool comprising:a pad carrier coupled to a tool body, wherein the pad carrier is radially movable relative to the tool body;a first isolation pad and a second isolation pad coupled to the tool body, wherein each of the first isolation pad and the second isolation pad is axially movable along the tool body; anda mechanism selectively coupling one of the first isolation pad and the second isolation pad to the pad carrier.2. The tool of claim 1 , wherein the first isolation pad is detachably coupled to the pad carrier by sliding into one or more grooves on the pad carrier.3. The tool of claim 1 , further comprising a probe claim 1 , wherein the probe is operable to selectively engage and disengage at least one of the pad carrier and the first isolation pad.4. The tool of claim 3 , wherein the probe prevents axial movement of the first isolation pad along the tool body.5. The tool of claim 1 , wherein at least one of the first isolation pad and the second isolation pad is placed inside a protective guard.6. The tool of claim 1 , wherein the mechanism selectively coupling one of the first isolation pad and the second isolation pad to the pad carrier comprises a linear actuator adapter.7. A formation testing device comprising:a probe for obtaining formation samples, wherein the probe is operable to engage a pad carrier;a first isolation pad detachably couplable to the pad carrier, wherein the first ...

Flow regime identification in formations using pressure derivative analysis with optimized window length

A method of investigating an earth formation. A tool having a pressure sensor is used in a borehole to collect formation fluid pressure data over time. A pressure derivative curve is generated from the formation fluid pressure data by conducting a piecewise linear regression of the data having optimal window length values L determined by calculating a derivative with respect to L of a pressure derivative value (DD), and selecting values of L where DD has a transition that departs from oscillatory behavior to gradual change. The pressure derivative is calculated with piecewise linear regression with the optimal window length values 2L. Different L values are generated for different groups of data points obtained over time. The pressure derivative is then used for flow regime determination.

ACOUSTIC TESTING OF CORE SAMPLES

A central member defines a sample chamber and includes an elastic material configured to enclose at least a portion of a sample, acoustic sensors configured to detect sound waves in the sample chamber, and acoustic emitters configured to emit sounds waves in the central member. A pressure-retaining case is configured to contain a pressurized fluid between an annulus formed between the pressure-retaining case and the central member. A switch is configured to connect or disconnect a pulser and receiver circuit to a specified emitter of the acoustic emitters. A data acquisition unit is configured to receive a signal from each of the acoustic sensors. A pulser and receiver circuit is configured to send an electric pulse to an acoustic emitter and a control signal to the data acquisition unit. 1. A system comprising:a central member defining a sample chamber, wherein the central member is configured to enclose at least a portion of a sample within the sample chamber, and wherein the central member comprises a plurality of acoustic sensors configured to detect sound waves in the sample chamber and a plurality of acoustic emitters configured to emit sounds waves in the sample chamber;a pulser and receiver circuit;a switch coupled to the pulse and receiver circuit and to each of the acoustic emitters, wherein the switch is configured to connect or disconnect the pulser and receiver circuit to a specified one of the acoustic emitters;a data acquisition unit coupled to the pulser and receiver circuit and to each of the acoustic sensors, wherein the data acquisition unit is configured to receive a respective signal from each of the acoustic sensors; andwherein the pulser and receiver circuit is configured to transmit an electric pulse to the specified one of the plurality of acoustic emitters through the switch and to transmit a first control signal to the data acquisition unit.2. The system of claim 1 , wherein the electric pulse causes the specified one of the plurality of ...

FORMATION TESTING

Formation testing which may involve circulating mud in a pipe string from a mud pit through a port in the pipe string to a downhole diverter sub, wherein the pipe string is suspended in a wellbore extending into a subterranean formation, operating a downhole pump to pump formation fluid from the formation, wherein the formation fluid comprises gas, and mixing the pumped formation fluid with circulated mud such that a proportion of the pumped formation gas in the circulated mud is maintained below a threshold value. 1. A method , comprising:(a) collecting data pertaining to at least one of a subterranean formation penetrated by a wellbore and a fluid in the subterranean formation;(b) determining initial threshold values of test operating parameters for a test to be performed utilizing a testing tool positioned in the wellbore proximate the subterranean formation, wherein determining the initial threshold values is based on the collected data and a testing tool configuration to be utilized to perform the test;(c) predicting wellbore fluid pressures along an open hole portion of the wellbore by performing a thermo-hydraulic simulation of the test utilizing the determined initial threshold values and the testing tool configuration; a value of at least one of the test operating parameters; and', 'the testing tool configuration;, '(d) analyzing the predicted wellbore fluid pressures and, based thereon, determining that the predicted wellbore fluid pressures along the open hole portion of the wellbore are indicative of a well integrity problem, and then updating the test by adjusting at least one of(e) iteratively repeating (c) and (d) until analysis of the predicted wellbore fluid pressures along the open hole portion of the wellbore is not indicative of a well integrity problem; and then(f) performing the updated test via operation of the testing tool in the wellbore.2. The method of wherein:collecting data pertaining to at least one of the subterranean formation and the ...

PLASMA CHEMISTRY BASED ANALYSIS AND OPERATIONS FOR PULSE POWER DRILLING

Analysis of chemical and physical properties of drilling and formation fluids associated with pulse power drilling operations that are performed in a borehole extending below a surface into one or more layers of formation material are conducted to determine one or more properties associated with the formation material and/or the drilling and formation fluids.

Systems and methods for cleaning a well face during formation testing operations

A method of cleaning a well face during formation testing at a drill site is disclosed. A collection chamber disposed in a formation tester tool may be at least partially filled with cleansing fluid. The formation tester tool may be introduced into a wellbore and the cleansing fluid may be ejected through a probe coupled to the formation tester tool. The collection chamber may then be at least partially filled with a formation fluid sample. A face of the probe may be contacted by a retractable cleaning mechanism coupled to the formation tester tool.

Downhole Formation Testing and Sampling Apparatus Having a Deployment Linkage Assembly

A downhole formation testing and sampling apparatus. The apparatus includes a setting assembly and an actuation module that is operable to apply an axial compressive force to the setting assembly shifting the setting assembly from a radially contracted running configuration to a radially expanded deployed configuration. A plurality of probes is coupled to the setting assembly. Each probe has a sealing pad with an outer surface operable to seal a region along a surface of the formation to establish the hydraulic connection therewith when the setting assembly is operated from the running configuration to the deployed configuration. Each sealing pad has at least one opening establishing fluid communication between the formation and the interior of the apparatus. In addition, each sealing pad has at least one recess operable to establish fluid flow from the formation to the at least one opening. 1. A downhole formation testing and sampling apparatus comprising:a setting assembly having a radially contracted running configuration and a radially expanded deployed configuration;an actuation module operably associated with the setting assembly and operable to apply an axial compressive force to the setting assembly to shift the setting assembly from the running configuration to the deployed configuration; andat least one probe coupled to the setting assembly, the probe having a sealing pad with an outer surface operable to seal a region along a surface of the formation to establish a hydraulic connection therewith when the setting assembly is operated from the running configuration to the deployed configuration,wherein, the sealing pad has at least one opening establishing fluid communication between the formation and the interior of the apparatus; andwherein, the sealing pad has at least one recess operable to establish fluid flow from the formation to the at least one opening.2. The apparatus as recited in wherein the setting assembly further comprises a setting mandrel ...

Mud Filtrate Property Measurement For Downhole Contamination Assessment

A method and system for measuring drilling fluid filtrate. The method may comprise disposing a downhole fluid sampling tool into a wellbore at a first location, activating a pump to draw a solids-containing fluid disposed in the wellbore into the downhole fluid sampling tool, drawing the drilling fluid with the pump across the at least one filter to form a drilling fluid filtrate, drawing the drilling fluid filtrate with the pump through the channel to the at least one sensor section, and measuring the drilling fluid filtrate with the at least one sensor. A system may comprise a downhole fluid sampling tool. The downhole fluid sampling tool may comprise at least one multi-chamber section, at least one sensor section, at least one filter, a pump, and a channel. 1. A method for measuring drilling fluid filtrate , comprising: at least one multi-chamber section;', 'at least one sensor section, wherein at least one sensor is disposed in the at least one sensor section;', 'at least one filter, wherein the at least one filter is disposed in the at least one multi-chamber section; and', 'a channel, wherein the channel fluidly connects the at least one multi-chamber section to the at least one sensor section; and, 'disposing a downhole fluid sampling tool into a wellbore at a first location, wherein the downhole fluid sampling tool comprisesactivating a pump to draw a solids-containing fluid disposed in the wellbore into the downhole fluid sampling tool;drawing the drilling fluid with the pump across the at least one filter to form a drilling fluid filtrate;drawing the drilling fluid filtrate with the pump through the channel to the at least one sensor section; andmeasuring the drilling fluid filtrate with the at least one sensor.2. The method of claim 1 , wherein the at least one multi-chamber section comprises a plurality of chambers and wherein the filter is disposed in at least one of the plurality of chambers.3. The method of claim 1 , wherein the filter is disposed in ...

SYSTEMS AND METHODS FOR EVALUATING RESERVOIR SUPERCHARGED CONDITIONS

Downhole formation pressure testing systems are provide. The systems include a drawdown pump, a probe configured to engage with a borehole wall and extract fluid from a formation, and a control element operably connected to the probe and the drawdown pump to perform a formation pressure testing operation. The formation pressure testing operation includes extracting a fluid from the formation for at least three drawdown intervals, monitoring a fluid pressure for a response interval at an end of each drawdown interval, measuring a fluid pressure at an end of each response interval to obtain a data point for each response interval, wherein each response interval is of the same duration, and wherein at least three data points are obtained, and performing a best fit analysis on the at least three data points, wherein the best fit analysis calculates a formation pressure. 1. A downhole formation pressure testing system comprising:a drawdown pump;a probe configured to engage with a borehole wall and extract fluid from a formation; anda control element operably connected to the probe and the drawdown pump to control the probe and the drawdown pump to perform a formation pressure testing operation,wherein the formation pressure testing operation comprises:extracting a fluid from the formation for at least three drawdown intervals;monitoring a fluid pressure for a response interval at an end of each drawdown interval;measuring a fluid pressure at an end of each response interval to obtain a data point for each response interval, wherein each response interval is of the same duration, and wherein at least three data points are obtained; andperforming a best fit analysis on the at least three data points, wherein the best fit analysis calculates a formation pressure.2. The downhole formation pressure testing system of claim 1 , wherein the drawdown pump claim 1 , the probe claim 1 , and the control element are located in a bottomhole assembly.3. The downhole formation pressure ...

Flowline saturation pressure measurements

A method for sampling a downhole formation fluid includes pumping formation fluid into the flowline of a downhole sampling tool, measuring a saturation pressure of the formation fluid in the flowline while pumping, and adjusting the pumping rate such that the fluid pressure in the flowline remains within a predetermined threshold above the measured saturation pressure.

LWD IN-SITU SIDEWALL ROTARY CORING AND ANALYSIS TOOL

An apparatus for estimating a property of an earth formation includes a carrier configured to be conveyed through a borehole penetrating the formation and a single probe configured to be extended from the carrier and to seal with a wall of the borehole. The apparatus further includes a fluid analysis sensor disposed at the carrier and configured to sense a property of a formation fluid sample extracted from the formation by the probe. A coring device is disposed at the carrier and configured to extend into the probe, to drill into the wall of the borehole, and to extract a core sample. A core sample analysis sensor is disposed at the carrier and configured to sense a property of the core sample. A processor is configured to receive data from the fluid analysis sensor and the core sample analysis sensor and to estimate the property using the data. 1. An apparatus for estimating a property of an earth formation , the apparatus comprising:a carrier configured to be conveyed through a borehole penetrating the formation;a single probe configured to be extended from the carrier and to seal with a wall of the borehole;a fluid analysis sensor disposed at the carrier and configured to sense a property of a formation fluid sample extracted from the formation by the probe;a coring device disposed at the carrier and configured to extend into the probe, to drill into the wall of the borehole, and to extract a core sample;a core sample analysis sensor disposed at the carrier and configured to sense a property of the core sample; anda processor configured to receive data from the fluid analysis sensor and the core sample analysis sensor and to estimate the property using the data.2. The apparatus according to claim 1 , further comprising a sealing pad disposed at the probe and configured to seal against the wall of the borehole.3. The apparatus according to claim 2 , further comprising:an actuator configured to apply pressure to the pad against the wall of the borehole;a sealing ...

FLUID SATURATED FORMATION CORE SAMPLING TOOL

Downhole core sampling apparatus including first and second sealing elements and at least one pump configured to pump wellbore fluid from the annular space defined by the sealing elements. The downhole core sampling apparatus is capable of obtaining formation fluid saturated core samples for laboratory testing and reservoir evaluation. Method and system for obtaining formation fluid saturated core samples from the sidewall of subterranean wellbores is provided. 1. A method of taking one or more formation fluid measurements of a formation comprising:disposing a downhole apparatus into a wellbore, wherein the downhole apparatus comprises a first sealing element, and a second sealing element;extending the first sealing element and the second sealing element within a wellbore;sealing the first sealing element and the second sealing element against the wellbore, the first sealing element longitudinally spaced from the second sealing element and defining, at least in part, an annular space corresponding to a formation access zone along a sidewall of the wellbore between the first sealing element and the second sealing element;pumping fluid out of the annular space through one or more ports disposed between the first sealing element and the second sealing element; andaccessing, with the downhole apparatus, at least a portion of the formation through the formation access zone to extract formation fluid from the formation for making the one or more formation fluid measurements.2. The method of claim 1 , wherein the downhole apparatus comprises a sidewall drilling tool and the method further comprising:accessing the at least a portion of the formation through the formation access zone with the sidewall drilling tool.3. The method of claim 2 , further comprising:drilling through at least a portion of the sidewall between the first sealing element and the second sealing element to expose the at least a portion of the formation to the annular space; andextracting the formation ...

FORMATION TESTER TOOL

A formation tester tool assembly includes a seal member mounted on rigid stabilizer that contacts a borehole wall separately from the seal member, so that seal exposure to a stabilization load that presses the tool against the borehole wall is limited or reduced by contact engagement of the stabilizer with the borehole wall. The stabilizer is provided by a hydraulically actuated probe piston reciprocally movable relative to a tool body on which it is mounted. The seal member is in some embodiments movable relative to the probe piston, for example being configured for hydraulic actuation to sealingly engage the borehole wall while the tool body is stabilized by action of the probe piston. 1. A tool assembly comprising:a tool body defining a tool axis, the tool body configured to be receivable in a borehole defined by a borehole wall;a stabilizer mounted on the tool body, the stabilizer displaceable in a direction transverse to the tool axis; a retracted position in which the stabilizer is spaced from the borehole wall, and', 'a deployed position in which a contact surface of the stabilizer engages the borehole wall at a first location;, 'an actuating mechanism coupled to the stabilizer and configured to move the stabilizer betweena seal mounted on the stabilizer and configured to sealingly engage the borehole wall at a second location when the stabilizer is in the deployed position to define a sealed isolation zone isolated from borehole fluids; wherein the second location is spaced from the first location; anda testing mechanism within the tool body and configured for testing one or more formation properties in the isolation zone.2. The tool assembly of claim 1 , further comprising a bias mechanism configured to press the seal radially against the borehole wall when the stabilizer is in the deployed position claim 1 , the bias mechanism acting between the stabilizer and the seal.3. The tool assembly of claim 1 , wherein:the stabilizer comprises a probe piston that ...

DOWNHOLE ROBOTIC ARM

An apparatus for manipulating an object in a borehole in an earthen formation includes a body configured to be conveyed along the borehole and a plurality of linear actuators disposed in the body and operatively connected to the object. The plurality of linear actuators applies a translational and rotational movement to the object. A related method includes applying a translational and rotational movement to the object using the plurality of linear actuators. 1. An apparatus for manipulating an object in a borehole in an earthen formation , comprising:a body configured to be conveyed along the borehole; anda plurality of linear actuators disposed in the body and operatively connected to the object, the plurality of linear actuators applying a translational and rotational movement to the object.2. The apparatus of claim 1 , wherein the plurality of linear actuators includes a first and a second linear actuator claim 1 , the first and the second linear actuator each having a first end operatively connected to the object claim 1 , and a second end operatively connected to the body claim 1 , at least one of the first and second linear actuators operatively connected to the body including a joint allowing relative rotational movement.3. The apparatus of claim 1 , wherein the plurality of linear actuators includes a first and a second actuator claim 1 , the first linear actuator having an end operatively connected to the body claim 1 , the second linear actuator having a first end operatively connected to the first linear actuator and a second end operatively connected to the body.4. The apparatus of claim 1 , further comprising at least one fluid channel through the body claim 1 , the at least one fluid channel conveying a fluid during borehole operation.5. The apparatus of claim 1 , further comprising at least one sensor associated with the plurality of linear actuators or the object claim 1 , the at least one sensor measuring a movement of at least one of the plurality ...

Fluid Compensation System for Downhole Sampling Bottle

A formation fluid sampling bottle having a first chamber and a first piston slidably disposed within the first chamber and dividing the first chamber into first and second portions. The sampling bottle has a second chamber and a second piston slidably disposed within the second chamber and dividing the second chamber into third and fourth portions. The third portion of the second chamber is fluidly connected with the second portion of the first chamber, and the fourth portion of the second chamber is fluidly connected with a space external to the sampling bottle. 1. An apparatus comprising: a first chamber;', 'a first piston slidably disposed within the first chamber and dividing the first chamber into first and second portions;', 'a second chamber; and', 'a second piston slidably disposed within the second chamber and dividing the second chamber into third and fourth portions, wherein the third portion is fluidly connected with the second portion, and wherein the fourth portion is fluidly connected with a space external to the sampling bottle., 'a formation fluid sampling bottle comprising2. The apparatus of wherein the first chamber comprises a port at least partially extending between the first chamber with a source of formation fluid claim 1 , and wherein the port is operable to communicate the formation fluid from the source of the formation fluid into the first portion of the first chamber.3. The apparatus of wherein the source of the formation fluid comprises a downhole pump.4. The apparatus of wherein the source of the formation fluid comprises a downhole rock formation.5. The apparatus of wherein the fourth portion is located downhole of the third portion.6. The apparatus of wherein the space external to the sampling bottle comprises a wellbore annulus surrounding the apparatus claim 1 , wherein the second and third portions contain a buffer fluid claim 1 , and wherein during downhole sampling operations:the first portion is operable to receive formation ...

SYSTEM AND METHOD RELATED TO A SAMPLING PACKER

A technique involves collecting formation fluids through a single packer. The single packer comprises an outer bladder with drains positioned in the outer bladder to obtain formation fluid samples. Features also may be incorporated into the single packer to limit sealing in the circumferential spaces between the drains and to provide a larger sampling surface than provided simply via the drain surface area. 1. A system for collecting fluid from a specific region of a wellbore , comprising: an outer bladder expandable in a wellbore across an expansion zone to contact and fluidly separate a first portion of the wellbore from a second portion of the wellbore, wherein the outer bladder having a plurality of drains for receiving formation fluid into the packer;', 'an inflatable bladder disposed within the outer bladder; and', 'a plate positioned in a circumferential space between a first drain and a second drain of the plurality of drains to limit sealing in the circumferential space between the first drain and the second drain., 'a packer comprising2. The system as recited in claim 1 , wherein the plurality of drains comprise a third drain positioned at a different axial and radial position from the first drain and the second drain claim 1 , the third drain positioned closer to an end of the packer than the first drain and the second drain.3. The system as recited in claim 1 , wherein the plate extends over the first drain if the single packer is in a contracted state and exposes the first drains if the single packer is in an expanded state.4. The system as recited in claim 3 , wherein the plate has a length defined by a first end opposite a second end claim 3 , the first end adjacent the first drain and the second end adjacent the second drain claim 3 , and further wherein the first drain moves away from the first end as the packer expands to expose the first drain.5. The system as recited in claim 1 , wherein the plate prevents any fluid seal between the first drain ...

Determination of mud-filtrate contamination and clean formation fluid properties

A system to determine a contamination level of a formation fluid, the system including a formation tester tool to be positioned in a borehole, wherein the borehole has a mixture of the formation fluid and a drilling fluid and the formation tester tool includes a sensor to detect time series measurements from a plurality of sensor channels. The system includes a processor to dimensionally reduce the time series measurements to generate a set of reduced measurement scores in a multi-dimensional measurement space and determine an end member in the multi-dimensional measurement space based on the set of reduced measurement scores, wherein the end member comprises a position in the multi-dimensional measurement space that corresponds with a predetermined fluid concentration. The processor also determines the contamination level of the formation fluid at a time point based the set of reduced measurement scores and the end member.

Scattering Detection from Downhole Optical Spectra

Obtaining in-situ, at a first time, first optical spectral data associated with a formation fluid flowing through a downhole formation fluid sampling apparatus, and then obtaining in-situ, at a second time after the first time, second optical spectral data associated with the formation fluid flowing through the downhole formation fluid sampling apparatus. A wavelength-independent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is then determined based on the first and second optical spectral data, and a wavelength-dependent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is determined based on the first and second optical spectral data. 1. A method , comprising:obtaining in-situ, at a first time, first optical spectral data associated with a formation fluid flowing through a downhole formation fluid sampling apparatus;obtaining in-situ, at a second time after the first time, second optical spectral data associated with the formation fluid flowing through the downhole formation fluid sampling apparatus;determining a wavelength-independent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus based on the first and second optical spectral data; anddetermining a wavelength-dependent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus based on the first and second optical spectral data.2. The method of further comprising adjusting an operating parameter associated with the downhole formation fluid sampling apparatus based on at least one of the determined wavelength-independent scattering intensity and the determined wavelength-dependent scattering intensity.3. The method of wherein the operating parameter is an operating parameter of a pump of the downhole formation fluid sampling apparatus.4. The method of wherein adjusting ...

Expandable Filtering System For Single Packer Systems

An arrangement having a body with at least one drain provided in the body is disclosed. The drain is configured to receive fluid when the body is expanded from a first unexpanded condition to a second expanded condition. At least one flowline is connectable to the drain. A screen is positioned over the drain and is configurable to expand from the first unexpanded condition to the second expanded condition. 1. A system comprising:a body having a plurality of fluid ports positioned radially about the body, the body expandable or inflatable from a first position to a second position such that a diameter of the body at the first position is less than a diameter of the body at the second position, wherein at least one of the plurality of fluid ports is positioned a radial distance from another one of the plurality of fluid ports;a filter positioned about at least one of the plurality of fluid ports to prevent debris from passing into the fluid port.2. The system according to claim 1 , wherein the filter is configured to expand in length or diameter from the first position to the second position.3. The system according to wherein the filter expands at least in part by a first portion of the filter moving with respect to a second portion of the filter.4. The system according to wherein the filter comprises a ball shaped material having gaps between the material sized to receive the fluid and prevent the debris.5. The system according to claim 3 , wherein the filter is located in a track in an outer layer of the body.6. The system according to claim 1 , wherein the filter comprises a bead material covered by an expandable material.7. The system according to claim 1 , further comprising:a base supporting the filter, wherein the base is configured with anti-extrusion fibers.8. The system according to claim 6 , wherein the filter is connected to an outer seal layer of the body.9. The system according to claim 1 , wherein the plurality of ports comprise at least a first port ...

Fluid Identification Via Pressure

Apparatus and methods for assessing contamination of formation fluid. A downhole sampling tool is operated to draw fluid from a subterranean formation into a chamber of the downhole sampling tool. The downhole sampling tool is then operated to discharge the fluid from the chamber while monitoring pressure of the fluid and volume of the chamber. Contamination of the discharged fluid is assessed based on the monitored fluid pressure and the monitored chamber volume. 1. A method comprising:operating a downhole sampling tool to draw fluid from a subterranean formation into a chamber of the downhole sampling tool;operating the downhole sampling tool to discharge the fluid from the chamber while monitoring pressure of the fluid and volume of the chamber; andassessing contamination of the discharged fluid based on the monitored fluid pressure and the monitored chamber volume.2. The method of further comprising determining a ratio between the monitored fluid pressure and the monitored chamber volume claim 1 , wherein assessing the contamination of the discharged fluid is based on the determined ratio.3. The method of wherein operating the downhole sampling tool to draw fluid from the subterranean formation into the chamber comprises decreasing pressure within the chamber to below a bubble point pressure of solution gas in the fluid.4. The method of wherein operating the downhole sampling tool to discharge the fluid from the chamber directs the discharged fluid through a fluid path between the chamber and a wellbore in which the downhole sampling tool is disposed adjacent the subterranean formation claim 1 , and wherein the fluid path includes a valve.5. The method of wherein the valve is a check valve having a set pressure that is substantially greater than a wellbore pressure of fluid within the wellbore surrounding the downhole sampling tool claim 4 , such that the monitored fluid pressure ultimately exceeds the wellbore pressure before the fluid discharged from the ...

Apparatus and methods for analysis of reservoir fluids

Methods and apparatus are provided for the measurement of the compressibility of reservoir fluid. A piezoelectric material is coupled to a wall of a fluid chamber. Compressibility is derived from measured pressure changes to the fluid resulting from volumetric changes to the fluid chamber imposed by the mechanical strain of the piezoelectric material resulting from an applied electric field.

ACOUSTIC TESTING OF CORE SAMPLES

A central member defines a sample chamber and includes an elastic material configured to enclose at least a portion of a sample, acoustic sensors configured to detect sound waves in the sample chamber, and acoustic emitters configured to emit sounds waves in the central member. A pressure-retaining case is configured to contain a pressurized fluid between an annulus formed between the pressure-retaining case and the central member. A switch is configured to connect or disconnect a pulser and receiver circuit to a specified emitter of the acoustic emitters. A data acquisition unit is configured to receive a signal from each of the acoustic sensors. A pulser and receiver circuit is configured to send an electric pulse to an acoustic emitter and a control signal to the data acquisition unit. 1. A testing apparatus comprising:a central member defining a sample chamber and comprising an elastic material configured to enclose at least a portion of a sample and a plurality of acoustic receivers configured to detect sound waves in the sample chamber and a plurality of acoustic transmitters configured to emit sounds waves in the central member; anda pressure-retaining case surrounding a radial surface of the central member, the pressure-retaining case configured to contain a pressurized fluid between an annulus formed between the pressure-retaining case and the central member.2. The testing apparatus of claim 1 , wherein the acoustic transmitters are ultrasonic emitters and the acoustic receivers are ultrasonic acoustic sensors.3. The testing apparatus of claim 1 , wherein the pressure-retaining case comprises: an upper portion; and', 'a lower portion connected to the upper portion along a first edge of the upper portion and a first edge of the lower portion by a hinge, a second edge of the upper portion and a second edge of the lower portion configured to abut one another when the case central member is in a closed position, the upper portion and the lower portion defining ...

SYSTEM FOR DETERMINING RATE OF GROUND WATER RE-CONTAMINATION DUE TO ROCK MATRIX BACK DIFFUSION

The present invention is a low permeability rock matrix back diffusion testing system and method which enables contaminant concentrations and hydraulic pressure values to be independently tested. This system includes specially configured packer components which allow precise placement and maintain test conditions for the duration of a study to accurately measure and predict the rate of back flow diffusion over time in low permeability zones. 1. A low permeability rock matrix back diffusion testing system comprised of:an upper conformable barrier and a lower conformable barrier which form an upper seal and a lower seal when in contact with the inner surface of a borehole;wherein said upper seal and said lower seal form a plurality of test zones comprised of a lower test zone, a central isolated test zone and an upper test zone wherein each of said test zones has measurable chemical concentration values and hydraulic pressure values;at least one lower test zone water line coupled with a lower test zone pump to enable the extraction of water from said lower test zone;an air sparging conduit operatively coupled with a pressurized air source to expel contaminants from said central isolated test zone, wherein said air sparging conduit passes through said upper conformable barrier; anda sparged contaminant conduit which passes though said upper barrier and said lower barrier to conduct sparged contaminants from said central isolated test zone.2. The system of which includes a test zone air line which conducts air to said lower test zone pump claim 1 , which conducts water through said lower test zone water line and enables testing to obtain the hydraulic pressure values of said lower test zone independently from said central isolated test zone.3. The system of which includes a component for adjusting said hydraulic pressure values of said lower test zone while said hydraulic pressure values of said central isolated test zone remain constant.4. The system of which further ...

DUAL FLOWLINE TESTING TOOL WITH PRESSURE SELF-EQUALIZER

Flowline pressure equalizer systems, methods and/or apparatuses for use on a downhole tool are provided. A pressure equalizer may be provided in communication with two flowlines. The pressure equalizer may use equalizing chambers and equalizing pistons to regulate pressure in one or both flowlines. Further, one or more flow routing modules may be interchangeable to further alter the flow scheme between the flowlines. Different plugs may house various flow routing configurations such that the plugs may be installed and/or removed in the tool string automatically or by a user. 1. A tool , comprising:a body configured to expand from a first outer diameter to a second outer diameter;at least one sample port in the body configured to accept a fluid in an environment;at least one guard port in the body configured to accept the fluid in the environment;at least one flow line configured to extend from each of the sample port and the guard port to transport fluid; anda pressure equalizer configured between at least two flowlines.2. The tool according to claim 1 , wherein the pressure equalizer is positioned at a field joint.3. The tool according to claim 1 , further comprising:a focused sampling module.4. The tool according to claim 3 , further comprising:a fluid analyzer module.5. The tool according to claim 4 , wherein the pressure equalizer is configured between the focused sampling module and the fluid analyzer module.6. The tool according to claim 1 , wherein the pressure equalizer is configured with an actuator.7. The tool according to claim 6 , wherein the actuator is a piston.8. The tool according to claim 6 , wherein the actuator is a diaphragm.9. The tool according to claim 6 , wherein the actuator is a series of stepped pistons. The present disclosure claims the benefit of U.S. Provisional Patent Application 61/726872, filed Nov. 15, 2012, the entirety of which is incorporated herein by reference.Aspects generally relate to evaluation of a subterranean formation. ...

Annular detachable rubber probe sidewall contact device

An annular detachable rubber probe sidewall contact device includes: a body which is columnar, wherein a high-pressure output oil path and a high-pressure retracting oil path are arranged in the body; a sidewall contact arm comprising multiple polar plates which are symmetrically distributed on an external circumference of the body, wherein each of the polar plates is movably installed on the body through a piston rod, and the piston rod is perpendicular to the body; the body has a piston cavity for accommodating the piston rod, and the piston cavity communicates with both the high-pressure output oil path and the high-pressure retracting oil path; and a sampling pipe, wherein one end of the sampling pipe is connected to the polar plates, and the other end of the sampling pipe communicates with a sampling channel in the body through a sampling cavity in the body. 1. An annular detachable rubber probe sidewall contact device , comprising:a body which is columnar, wherein a high-pressure output oil path and a high-pressure retracting oil path are arranged in the body;a sidewall contact arm comprising multiple polar plates which are symmetrically distributed on an external circumference of the body, wherein each of the polar plates is movably installed on the body through a piston rod, and the piston rod is perpendicular to the body; the body has a piston cavity for accommodating the piston rod, and the piston cavity communicates with both the high-pressure output oil path and the high-pressure retracting oil path; anda sampling pipe, wherein one end of the sampling pipe is connected to the polar plates, and the other end of the sampling pipe communicates with a sampling channel in the body through a sampling cavity in the body.2. The annular detachable rubber probe sidewall contact device claim 1 , as recited in claim 1 , whereintotally three the polar plates are distributed on the external circumference of the body with spacing of 120 degrees.3. The annular ...

Downhole Sampling Probe with Penetrating Inlet and Method of Using Same

A probe of a downhole tool deployable into a wellbore penetrating a subterranean formation is provided. The downhole tool has at least one flowline extendable therein. The formation has a clean fluid therein. The probe includes a base carried by the downhole tool and positionable adjacent a wall of the wellbore, a penetrating inlet carried by the base and having a tip about a sampling end thereof to receive the clean fluid, and an inlet packer. The penetrating inlet is in fluid communication with the at least one flowline, and extendable through the wall of the wellbore a distance into the formation. The inlet packer is inflatably positionable about the penetrating inlet to form a seal with the formation and isolate the tip therein whereby the clean fluid may be drawn from the formation and into the downhole tool. 1. A probe of a downhole tool deployable into a wellbore penetrating a subterranean formation , the downhole tool having at least one flowline extendable therein , the formation having a clean fluid therein , the probe comprising:a base carried by the downhole tool and positionable adjacent a wall of the wellbore;a penetrating inlet carried by the base and having a tip about a sampling end thereof to receive the clean fluid, the penetrating inlet in fluid communication with the at least one flowline, the penetrating inlet extendable through the wall of the wellbore a distance into the formation; andan inlet packer inflatably positionable about the penetrating inlet to form a seal with the formation and isolate the tip therein whereby the clean fluid may be drawn from the formation and into the downhole tool.2. The probe of claim 1 , wherein the tip is selectively extendable from the penetrating inlet.3. The probe of claim 1 , wherein the tip is extendable from the penetrating inlet.4. The probe of claim 1 , wherein the penetrating inlet comprises a sampling intake and a packer flow tube positionable about the sampling intake claim 1 , the sampling intake ...

Apparatus and methods for high quality analysis of reservoir fluids

Methods and systems for collecting high quality reservoir samples are disclosed. The systems and methods of the present invention are especially important in collecting samples of reservoir fluids in a manner that most closely resembles production fluids. The systems include an upper shoe and a lower shoe that are asymmetrically spaced along the axial length of probe module with respect to a sampling probe to allow for the placement of a component compartment proximate the probe. Sensors or modules for testing or analyzing reservoir fluids are positioned within the compartment.

System And Method For Graphene-Structure Detection Downhole

A method may comprise sampling a wellbore fluid; analyzing the wellbore fluid and determining a presence of a graphene-like substrate, a concentration of the graphene-like substrate, or both, in the wellbore fluid; and correlating the presence and the concentration of the graphene-like substrate to at least one subterranean formation characteristic. 1. A method comprising:sampling a wellbore fluid;analyzing the wellbore fluid and determining a presence of a graphene-like substrate, a concentration of the graphene-like substrate, or both, in the wellbore fluid; andcorrelating the presence and the concentration of the graphene-like substrate to at least one subterranean formation characteristic.2. The method of claim 1 , wherein sampling the wellbore fluid comprises sampling in a wellbore using a wellbore sampling tool.3. The method of claim 1 , wherein sampling the wellbore fluid comprises sampling at a surface of the wellbore by pumping the wellbore fluid out of the wellbore.4. The method of claim 1 , wherein determining a presence of the graphene-like substrate comprises detecting a characteristic signal of graphene-like substrates.5. The method of claim 4 , wherein the characteristic signal is a spectrographic peak.6. The method of claim 5 , wherein the spectrographic peak is at least about 2700 cmfor a Raman shift.7. The method of claim 5 , wherein the spectrographic peak is at least about 284 eV binding energy for X-ray photoelectron spectroscopy.8. The method of claim 1 , wherein the at least one subterranean formation characteristic comprises at least one of reservoir architecture claim 1 , interval productivity claim 1 , reservoir charging mechanisms claim 1 , reservoir filling history claim 1 , reservoir migration pathways claim 1 , or combinations thereof9. The method of claim 8 , wherein the reservoir architecture comprises at least one of trap configuration claim 8 , seal capacity claim 8 , a base of a producing zone claim 8 , or combinations thereof.10. ...

Downhole Fluid Analysis Methods For Determining Viscosity

The present disclosure relates to methods and apparatus for determining a viscosity-pressure profile of downhole fluid by measuring the viscosity at several different pressures during a sampling operation. According to certain embodiments, the viscosity may be measured at different times during a sampling operation and used to generate the viscosity-pressure profile. For example, the viscosity may be measured at the beginning of pumping, during filling of a sample chamber, during a pressure-build up period, and while retracting the probe. The measured viscosities may then be employed to determine a profile that represents the change in viscosity that occurs with pressure. 1. A downhole tool comprising:a pressure sensor to measure pressures of formation fluid within a flowline during a pumping phase, a sample chamber filling phase, a pressure build-up phase, and a probe retraction phase of a sampling operation;a viscosity sensor to measure viscosities of the formation fluid within the flowline during the pumping phase, the sample chamber filling phase, the pressure build-up phase, and the probe retraction phase; anda controller configured to execute instructions stored within the downhole tool to determine a pressure-viscosity profile based on the measured pressures and viscosities.2. The downhole tool of claim 1 , comprising a fluid analyzer to determine properties of the formation fluid claim 1 , wherein the controller is configured to initiate the sample chamber filling phase based on the fluid properties.3. The downhole tool of claim 1 , comprising an extendable probe to direct the formation fluid into the downhole tool.4. The downhole tool of claim 3 , wherein the probe is engaged with a wellbore wall during the pumping phase claim 3 , the sample chamber filling phase claim 3 , and the pressure build-up phase.5. The downhole tool of claim 1 , comprising a pump to direct the formation fluid through a flowline during the pumping phase and the sample chamber ...

METHOD AND APPARATUS FOR SUB-TERRAIN CHLORINE ION DETECTION IN THE NEAR WELLBORE REGION IN AN OPEN-HOLE WELL

Methods and systems for identifying a salinity gradient in a formation surrounding a bore of a subterranean well includes introducing an antenna assembly into the bore of the subterranean well. The antenna assembly has an elongated antenna body. An emitting antenna extends axially along an outer surface of the antenna body. A receiving antenna extends axially along the outer surface of the antenna body, the receiving antenna being spaced circumferentially apart from the emitting antenna. An electromagnetic interrogation wave is produced into the formation with the emitting antenna with a pulse duration of no greater than 0.01 seconds. A reflected wave is received with the receiving antenna. The amplitude of the reflected wave is analyzed to determine a distribution of chlorine ion concentration in the formation. 1. A method for identifying a salinity gradient in a formation surrounding a bore of a subterranean well , the method including: an elongated antenna body;', 'an emitting antenna extending axially along an outer surface of the antenna body; and', 'a receiving antenna extending axially along the outer surface of the antenna body, the receiving antenna being spaced circumferentially apart from the emitting antenna;, 'introducing an antenna assembly into the bore of the subterranean well, the antenna assembly havingproducing an electromagnetic interrogation wave into the formation with the emitting antenna with a pulse duration of no greater than 0.1 seconds;receiving a reflected wave with the receiving antenna; andanalyzing an amplitude of the reflected wave to determine a distribution of chlorine ion concentration in the formation.2. The method of claim 1 , where the emitting antenna is printed on the outer surface of the antenna body and where the receiving antenna is printed on the outer surface of the antenna body.3. The method of claim 1 , where the emitting antenna and the receiving antenna have the same shape claim 1 , and where the shape is non-linear. ...

Downhole Tool Centralizing Pistons

The present disclosure is directed to setting pistons designed to centralize downhole tools within a wellbore. In one embodiment, a downhole tool includes a probe extendable to engage a wall of a wellbore and a setting piston extendable towards the wall of the wellbore. A roller is coupled to the setting piston and designed to roll circumferentially along the wall to pivot the downhole tool within the wellbore.

HIGH TEMPERATURE, BI-DIRECTIONAL SHEAR SEAL AND RELATED METHODS

A valve includes an outer piston, an inner piston telescopically disposed in the outer piston. A cavity separates at least a portion of the inner piston and the outer piston. The valve also includes a seal disposed in the cavity and that forms an upper pressure chamber and a lower pressure chamber. A first flow space connects the lower pressure chamber with a first flow path and a second flow space connects the upper pressure chamber with a second flow path. A biasing member engages the inner and outer piston. 1. A valve , comprising:an outer piston;an inner piston telescopically disposed in the outer piston, wherein a cavity separates at least a portion of the inner piston and the outer piston;a seal disposed in the cavity and forming an upper pressure chamber and a lower pressure chamber;a first flow space connecting the lower pressure chamber with a first flow path;a second flow space connecting the upper pressure chamber with a second flow path; anda biasing member engaging the inner and outer piston.2. The valve of claim 1 , wherein: a head having a sealing surface,', 'an axial bore extending therethrough,', 'a shaft section extending from the head,', 'a step formed along the shaft section, and', 'a diametrically reduced bore section formed adjacent the step;, 'the outer piston includes a head having a sealing surface,', 'a shaft section extending from the head,', 'a shoulder formed along the shaft section,', 'a diametrically reduced distal end; and, 'the inner piston includesthe cavity is formed between the step of the outer piston and the shoulder of the inner piston.3. The valve of claim 1 , wherein the biasing member is disposed around the shaft section of the outer piston and applies a biasing force against the heads of the inner piston and the outer piston.4. The valve of claim 1 , wherein the first flow space including at least a portion of the axial bore of the outer piston claim 1 , and a space between the diametrically reduced distal end and the outer ...

METHODS AND SYSTEMS FOR RESERVOIR CHARACTERIZATION AND OPTIMIZATION OF DOWNHOLE FLUID SAMPLING

A method (and corresponding downhole tool) is provided for downhole fluid analysis of formation fluids. The downhole tool is operated to draw live fluid from the formation through the downhole tool and acquire observed sensor measurements of the live fluid (which includes filtrate contamination) that flows through the downhole tool. The observed sensor measurements are used in an inversion process that solves for a set of input parameter values of a computational model that predicts level of filtrate contamination in the live fluid that flows through the downhole tool. The set of input parameter values includes at least one endpoint value for the observed sensor measurements. The set of input parameter values solved by the inversion process can be stored and output for different applications. 1. A method for downhole fluid analysis of formation fluids , comprising:with a downhole tool positioned in a wellbore that traverses a subterranean formation, operating the downhole to draw live fluid from the formation through the downhole tool and acquire observed sensor measurements of the live fluid that flows through the downhole tool, wherein the live fluid includes filtrate contamination;using the observed sensor measurements in an inversion process that solves for a set of input parameter values of a computation model that predicts level of filtrate contamination in the live fluid that flows through the downhole tool, wherein the set of input parameter values comprises at least one endpoint value for the observed sensor measurements; andstoring and outputting the set of input parameter values solved by the inversion process.2. A method according to claim 1 , further comprising:using the set of input parameter values solved by the inversion process to calibrate the computational model;using the calibrated computational model to predict level of filtrate contamination in the live fluid; andcomparing the predicted level of filtrate contamination to a threshold level and ...

Apparatus and Method for Obtaining Formation Fluid Samples Utilizing a Sample Clean-up Device

In one aspect, a method of obtaining a fluid from a formation is disclosed that in one embodiment may include: pumping fluid received by a first probe from the formation into the wellbore; pumping fluid received by a second probe from the formation into the wellbore; determining when the fluid received by one of the first and second probes is clean; and pumping the fluid received by the first probe into a sample chamber while collecting the formation fluid received by the second probe from the formation into a storage chamber having an internal pressure less than the pressure of the formation.

Modular Connector And Method

A downhole modular tool includes a first module, a second module, a third module, and one or more connectors for connecting the first, second, and third modules. Each module includes a drill collar, a drilling fluid passageway, a first fluid passageway, and a second fluid passageway. The one or more connectors connect any one of the first, second, and third modules, to another of the first, second, and third modules to transfer the drilling fluid, the first fluid, and the second fluid between the connected modules. 1. A modular downhole tool , comprising: a drill collar;', 'a drilling fluid passageway to direct a drilling fluid through the module;', 'a first formation fluid passageway to direct a first formation fluid through the module; and', 'a second formation fluid passageway to direct a second formation fluid through the module; and, 'a first module, a second module, and a third module, each comprisinga first connector configured to connect to an end of each of the first, second, and third modules to couple any one of the first, second, and third modules to another of the first, second, and third modules to transfer the drilling fluid, the first formation fluid, and the second formation fluid between the connected modules.2. The modular downhole tool of claim 1 , wherein the first connector comprises a body assembly for fluidly connecting the first formation fluid passageway of any one of the first claim 1 , second claim 1 , and third modules to the first formation fluid passageway of another of the first claim 1 , second and third modules.3. The modular downhole tool of claim 1 , wherein the first connector comprises a body assembly separate from the first module claim 1 , the second module claim 1 , and the third module.4. The modular downhole tool of claim 1 , wherein the first connector comprises a body assembly having a first fluid conduit configured to direct the first formation fluid through the connector claim 1 , and a second fluid conduit configured ...

Underground tool providing on-line information for in situ assessment of aquifer quality and flow rate

An underground sampling tool (HTMS) for underground water analysis of both quality and flow rate, providing the information required to perform an underground drilling and obtain uncontaminated water for crop irrigation, said tool comprising: a housing for the electronic and electrical controls, a housing for the hydraulic means controlled by the electric and electronic portion of the tool, a test body consisting of a variety of hydraulic circuits for operating the various operating valves of the tool, wherein said test body further comprises: a rear shoe on an axial axis of the tool, wherein said rear shoe is driven by two telescoping pistons simultaneously that arise from the inside of the tool when driven by a signal of a surface equipment operably enabled for this purpose, and a front shoe, driven by several pistons which are housed below the front shoe, not shown in the figures, and driven by one or more electro-pneumatic devices acting jointly and generating a progressive forward or backward movement of the front shoe. Process for the collection and analysis of samples in a wellbore using said tool.

PUSHING SITTING DEVICE

A pushing sitting device includes a main base, at least one set of pushing arms are provided on the side surface of the main base. The pushing arm includes a bi-parallelogram, having a first parallelogram structure and a second parallelogram structure. The first parallelogram structure includes a front arm, a detector assembly, an assisting arm and the main base, wherein the front arm is connected to the detector assembly and the main base respectively through joint pins at two ends, while the assisting arm is connected to the detector assembly and the main base respectively through the rotating shafts at two ends. The second parallelogram includes a rear arm, the detector assembly, a nonporous assisting arm and the main base which are connected in sequence by connecting shaft. 1. A pushing sitting device for the oil exploration and sample taking , comprises:a main base, on the side surface of which at least one set of the pushing arms are provided; each set of pushing arms include a bi-parallelogram that contains a first parallelogram structure and a second parallelogram structure; the first parallelogram includes a front arm, a detector assembly, an assisting arm and the main base, andwherein the front arm is connected to the detector assembly and the main base respectively via joint pins at two ends, while the assisting arm is connected to the detector assembly and the main base respectively via rotating shafts at two ends; the second parallelogram is constituted by a rear arm, the detector assembly, a nonporous assisting arm and the main base, the said components are connected to each other by connecting shaft.2. A pushing sitting device as claimed in claim 1 , wherein one or more front piston holes are provided in the left side of the main base corresponding to pushing arm claim 1 , each piston hole corresponds to a main pushing pistons; one or more piston holes are connected to each other through a first internal hole sealed by seal plug and thread screw plug ...

Reservoir Sampling Tools and Methods

Techniques for sampling a subsurface reservoir include lowering a downhole logging tool comprising one or more samplers, a cleaner system, and a sample probe bit into a borehole until at least one sampler is positioned correctly in a subterranean reservoir; advancing the cleaner system into the reservoir cleaning mud filtrate and contaminated reservoir material away into a mud column; advancing the sample probe bit into the reservoir; and solvent is injected into the reservoir from the solvent reservoir. 1. A system for sampling a subsurface reservoir comprising:a sampling device comprising a cylindrical member that comprises a closed distal end and an end member that extends from the closed distal end, the end member configured to extend a first distance beyond the closed distal end and penetrate into a wall of a subterranean reservoir to a first depth; anda sampling and recovery system positioned within the cylindrical member and configured to:penetrate through the closed distal end of the cylindrical member and into the subterranean reservoir to a second depth that is greater than the first depth; andrecover a sample of reservoir material or reservoir fluids from the reservoir.2. The system of claim 1 , wherein the cylindrical member further comprises a inner lumen claim 1 , and the sampling and recovery system comprises at least one of:a drill bit configured to penetrate through the closed distal end of the cylindrical member and into the subterranean reservoir to the second depth; ora cannula configured to penetrate through the closed distal end of the cylindrical member and into the subterranean reservoir to the second depth.3. The system of claim 2 , wherein the cannula comprises a side-port cannula.4. The system of any of the preceding claims claim 2 , wherein:the first depth is greater than a thickness of at least one of a contaminated layer coating the wall or invaded into the reservoir; andthe sample is substantially free of contaminants from the ...

Method And Apparatus For Water-Based Mud Filtrate Contamination Monitoring In Real Time Downhole Water Sampling

A method and apparatus for performing water based mud-filtrate contamination monitoring in real time through evaluation of downhole water sampling. 1. A method for contamination monitoring , comprising:measuring a water based mud filtrate density and a water based mud filtrate resistivity at surface conditions;converting the measured water based mud filtrate density and resistivity to downhole conditions;logging properties of a downhole fluid to find at least a resistivity and a density of a fluid sample at the downhole conditions;establishing a linear relationship between a water based mud filtrate conductivity at downhole conditions and the water based mud density at the downhole conditions;determining an existence of a high quality pressure gradient at the downhole conditions;fitting at least one of a density and a resistivity data using a power function and obtaining at least one of a density and a resistivity for native formation water when no high quality pressure gradient exists;estimating a density from the pressure from the high quality gradient when the high quality pressure gradient exists;estimating a resistivity for native formation water, using the linear relationship between the conductivity and the density;estimating a density for water based mud filtrate using the linear relationship between conductivity and density; andestimating a water based mud filtrate contamination.2. The method according to claim 1 , wherein the estimating the resistivity for native formation water is performed using the linear relationship between the conductivity and the density.3. The method according to claim 1 , wherein the estimating the resistivity for native formation water is performed using Archie's expression.4. The method according to claim 1 , further comprising:estimating a time required for sampling to reach a water based mud filtrate contamination level.6. The method according to claim 1 , wherein the determining the existence of the high quality pressure ...

SYSTEM AND METHOD FOR FLUID SEPARATION

This disclosure relates to a separating a fluid having multiple phases during formation testing. For example, certain embodiments of the present disclosure relate to receiving contaminated formation fluid on a first flow line and separating a contamination (e.g., mud filtrate) from the formation fluid by diverting the relatively heavier and/or denser fluid (e.g., the mud filtrate) downward through a second flow line and diverting the relatively lighter and/or less dense fluid upward through a third flow line. In some embodiments, the third flow line is generally oriented upwards at a height that may facilitate the separation of the heavier fluid from the relatively lighter fluid based on gravity and/or pumps. 1. A downhole acquisition tool , comprising: a conduit fluidly coupled to a geological formation and configured to receive the fluid from the geological formation;', 'a first vertical conduit fluidly coupled to the conduit, wherein the first vertical conduit is configured to receive the fluid and direct the fluid in a first direction, wherein the first direction is a downward direction;', 'a second vertical conduit fluidly coupled to the conduit and the first vertical conduit, wherein the second vertical conduit is configured to receive the fluid and direct the fluid in a second direction; and', 'a first flow control device positioned downstream along the first vertical conduit, wherein the first flow control device is configured to control a flow of the fluid along the first vertical conduit., 'a formation testing module comprising2. The downhole acquisition tool of claim 1 , comprising a separation chamber fluidly coupled to the conduit claim 1 , the first vertical conduit claim 1 , and the second vertical conduit.3. The downhole acquisition tool of claim 1 , wherein the second direction is in an upward direction. Any and all applications for which a foreign or domestic priority claim is identified in the Application Data Sheet as filed with the present ...

Multi-Probe Reservoir Sampling Device

A tool insertable into a wellbore for sampling formation fluids includes a body, and sample probe assemblies that project radially outward from the body and into sampling contact with the wellbore wall. Packers are provided on the outer terminal ends of the sample probe assemblies and which are urged against the wellbore wall. Actuator driven linkage assemblies selectively deploy and retract the packers from and back into the body. The sample probe assemblies are disposed at substantially the same axial location on the body, and are angularly spaced about an axis of the body. Each sample probe assembly is independently actuated, so that a discrete azimuthal portion can be sampled, and each has a dedicated sample container for storing sampled formation fluid. 1. A downhole tool for sampling formation fluid in a wellbore comprising:a body; and linkage assemblies,', 'pad assemblies that selectively project radially outward from the body on the ends of the linkage assemblies and into sampling engagement with a wall of the wellbore at substantially the same measured depth in the wellbore, and', 'actuators in the body coupled with each one of the linkage assemblies and that are each selectively operated independently from the other actuators., 'sample probe assemblies that comprise,'}2. The tool of claim 1 , further comprising sample tanks claim 1 , wherein each one of the sample tanks are in fluid communication with a one of the sampling pads claim 1 , so that formation fluid obtained by each of the sampling pads is stored in a one of the sample tanks.3. The tool of claim 2 , further comprising a conduit between each one of the pad assemblies and each one of the sample tanks.4. The tool of claim 1 , wherein each of the pad assemblies comprises a packer having an outer radial surface that contacts the wellbore wall claim 1 , and a port in a mid-portion of the outer radial surface that is in fluid communication with the formation fluid in a formation intersected by the ...

LWD Formation Tester with Retractable Latch for Wireline

A method comprising: without removing a BHA from a wellbore of a well extending into a formation, extending, into an interior flow bore of the BHA, a first component of a wet latch assembly to provide an extended first component of the wet latch assembly; conveying downhole via a wireline cable, from a surface through an interior flow bore provided by a drill string, a second component of the wet latch assembly, and coupling the second component of the wet latch assembly with the extended first component of the wet latch assembly such that an electrical connection is established between the first component and the second component and between the BHA and the surface via the wireline cable; and testing the formation with a formation tester of the BHA, while providing power and/or data telemetry for the formation tester via the wet latch assembly and the wireline cable. 1. A method comprising:without removing a BHA from a wellbore of a well extending into a formation, extending, into an interior flow bore of the BHA, a first component of a wet latch assembly to provide an extended first component of the wet latch assembly;conveying downhole via a wireline cable, from a surface through an interior flow bore provided by a drill string, a second component of the wet latch assembly, and coupling the second component of the wet latch assembly with the extended first component of the wet latch assembly such that an electrical connection is established between the first component and the second component and between the BHA and the surface via the wireline cable; andtesting the formation with a formation tester of the BHA, wherein testing the formation comprises providing power and/or data telemetry for the formation tester via the wet latch assembly and the wireline cable.2. The method of further comprising drilling claim 1 , with a drill bit on a downhole end of the drill string claim 1 , the wellbore claim 1 , wherein the drill string comprises a conveyance coupled to the ...

LWD Formation Tester with Retractable Latch for Wireline

A bottom hole assembly (BHA) comprising: a first component of a wet latch assembly, the first component configured for coupling, when extended into the interior flow bore of the BHA, with a second component of the wet latch assembly to provide an assembled wet latch assembly, such that an electrical connection can be made between the first component and the second component; and a formation tester operable for performing a formation test, the formation tester electrically connected with the first component of the wet latch assembly, such that power and/or telemetry can be provided to the formation tester via the assembled wet latch assembly during the formation test. 1. A bottom hole assembly (BHA) comprising:a first component of a wet latch assembly, the first component configured for coupling, when extended into the interior flow bore of the BHA, with a second component of the wet latch assembly to provide an assembled wet latch assembly, such that an electrical connection can be made between the first component and the second component; anda formation tester operable for performing a formation test, the formation tester electrically connected with the first component of the wet latch assembly, such that power and/or telemetry can be provided to the formation tester via the assembled wet latch assembly during the formation test.2. The BHA of further comprising a battery claim 1 , wherein the battery is electrically connected with the first component of the wet latch assembly claim 1 , such that power can be provided to the battery via the assembled wet latch assembly.3. The BHA of wherein the formation tester and/or another component of the BHA is electrically connected with the first component of the wet latch assembly claim 1 , such that telemetry of data can be provided from the formation tester and/or the another component of the BHA uphole via the assembled wet latch assembly.4. The BHA of claim 1 , wherein the first component of the wet latch assembly is ...

MEASURING HYDROCARBON CONTENT OF A ROCK FORMATION DOWNHOLE USING LASER-INDUCED VAPORIZATION AND PYROLYSIS

A downhole tool to make one or more downhole measurements of laser-induced vaporization and/or pyrolysis of hydrocarbons is provided and disposed at a desired location within a wellbore. A tool head of the downhole tool is brought into sealing engagement with the wellbore wall. The fluid within an interior region enclosed by the tool head and the wellbore wall is evacuated and a measurement spot is irradiated with a laser to generate volatile hydrocarbons and/or pyrolytic hydrocarbons. Measurements are made on the volatile hydrocarbons and/or pyrolytic hydrocarbons and one or more formation properties are inferred based on the measurements. A low level of laser radiation intensity, irradiating some or all of the wellbore wall enclosing the interior region, may be used to prevent measurement contamination, and both medium power and high power levels of laser radiation may be used to first vaporize and then pyrolyze the hydrocarbons. 1. An apparatus , comprising:a tool body deployable into a wellbore;a tool head carried by the tool body;a laser capable of delivering laser radiation to a desired formation penetrated by the wellbore; anda measurement system within the tool body.2. The apparatus of claim 1 , further comprising one or more pumps.3. The apparatus of claim 1 , further comprising one or more by-pass tubes.4. The apparatus of claim 1 , wherein the measurement system comprises a solid separator.5. The apparatus of claim 1 , wherein the measurement system comprises a measurement module.6. The apparatus of claim 5 , wherein the measurement module comprises a device selected from the group consisting of a mass spectrometer claim 5 , a photoionization detector claim 5 , and a thermal conductivity detector.7. The apparatus of claim 1 , wherein the tool head is an integral part of the tool body.8. The apparatus of claim 1 , wherein the tool head is mounted on an extendable pad.9. The apparatus of claim 1 , wherein the tool head is telescopic.10. The apparatus of ...

Determining Properties of OBM Filtrates

Methods and apparatus for operating a downhole tool within a wellbore adjacent a subterranean formation to pump contaminated fluid from the formation into the downhole tool while measuring first and second fluid properties of the contaminated fluid. The contaminated fluid comprises native fluid from the formation and a contaminant. The downhole tool is in communication with surface equipment located at surface. The downhole tool and/or surface equipment is operated to estimate a formation volume factor of the contaminated fluid based on at least one of the first and second fluid properties of the contaminated fluid. A linear relationship is then estimated between the first fluid property and a function that relates the first fluid property to the second fluid property and the estimated formation volume factor of the contaminated fluid. A fluid property of the contaminant is then estimated based on the estimated linear relationship. 1. A method , comprising:operating a downhole tool within a wellbore adjacent a subterranean formation to pump contaminated fluid from the subterranean formation into the downhole tool while measuring first and second fluid properties of the contaminated fluid, wherein the contaminated fluid comprises native fluid from the subterranean formation and a contaminant, estimate a formation volume factor of the contaminated fluid based on at least one of the first and second fluid properties of the contaminated fluid;', the second fluid property; and', 'the estimated formation volume factor of the contaminated fluid; and, 'estimate a linear relationship between the first fluid property and a function comprising, 'estimate a fluid property of the contaminant based on the estimated linear relationship., 'operating at least one of the downhole tool and the surface equipment to2. The method of further comprising estimating a contamination level of the contaminated fluid based at least on:the estimated formation volume factor of the contaminated ...

Setting two or more probes in a borehole for determining a one stop formation pressure gradient in the formation

Quality factors associated with formation pressure measurements at various depths in the geologic formation are determined based on one or more well logs of formation properties in a geologic formation. A formation testing tool with two or more probes is positioned in a borehole of the geologic formation based on the quality factors. The two or more probes in the borehole perform respective formation pressure measurements, where each formation pressure measurement is performed at a different depth. The formation pressure measurements and the given distance between the two or more probes indicate a formation pressure gradient.

Measuring and Adsorbing Chemical in Downhole Fluids

Interaction of adsorbing chemicals with a downhole tool presents inaccuracies in the adsorbing chemical measurement and analysis. The principles of the present disclosure provide a method and system of sampling fluids including an adsorbing chemical in a subterranean reservoir. One method may include modeling an interaction between the adsorbing chemical and a downhole tool, applying the model to a measurement of the adsorbing chemical, and adjusting the measurement in response to applying the model. 1. A tool for detection of an adsorbing chemical in a subterranean reservoir comprising:a formation tester having a sampling chamber to receive a fluid sample containing an adsorbing chemical; and measuring a concentration of the adsorbing chemical;', 'characterizing a response of the formation tester to the concentration of the adsorbing chemical over time; and', 'operating the tool in response to the characterization., 'a processor coupled to the formation tester to perform operations comprising2. The tool of claim 1 , wherein a detector for detecting the adsorbing chemical is located proximal to the sample chamber.3. The tool of claim 1 , wherein the adsorbing chemical is at least one of H2S claim 1 , mercury claim 1 , CO2 claim 1 , tracer claim 1 , water scaling chemical claim 1 , sulfur containing species claim 1 , or a mercaptian.4. The tool of claim 3 , wherein H2S is detected optically claim 3 , electrically claim 3 , or chemically.5. The tool of claim 2 , wherein the detector is a Gas Chromatograph.6. The tool of claim 5 , wherein the detector further comprises a sulfur detector.7. The tool of claim 5 , wherein the detector further comprises a nuclear magnetic resonance (“NMR”) device.8. The tool of claim 1 , wherein the adsorbing chemical is sampled from a supply chamber.9. The tool of claim 1 , wherein the adsorbing chemical is sampled from a formation fluid.10. The tool of claim 1 , wherein the characterization is performed downhole.11. The tool of claim 1 , ...

FOCUSED PROBE APPARATUS AND METHOD THEREFOR

Apparatus and methods for downhole formation testing including use of a probe having inner and outer channels adapted to collect or inject injecting fluids from or to a formation accessed by a borehole. The probe straddles one or more layers in laminated or fractured formations and uses the inner channels to collect fluid. 1. A formation tool comprising:a probe having an inner channel surrounded by an outer channel, the probe structured such that the inner channel and the outer channel have an elongate shape, the probe operable to engage a wall of a borehole and extract fluid from a formation adjacent the borehole;one or more transducers to regulate flow rate and/or pressure in the inner channel and the outer channel according to a relationship of flow rate and/or pressure of the inner channel to the outer channel; andpumps to pump the fluid through the probe, the pumps arranged to operatively clear the inner channel by pumping fluid out of the inner channel while pumping fluid into the outer channel or to operatively clear the outer channel by pumping fluid out of the outer channel while pumping fluid into the inner channel.2. The formation tool of claim 1 , wherein the probe is arranged to operatively capture more contaminated fluid in the outer channel than in the inner channel.3. The formation tool of claim 1 , wherein the probe includes an outer sealing member that encircles the outer channel.4. The formation tool of claim 1 , wherein the probe includes a sealing member between the inner flow channel and the outer flow channel.5. The formation tool of claim 4 , wherein the sealing member is a retractable sealing member.6. The formation tool of claim 1 , wherein the formation tool includes a first flow line coupled to the inner channel and a second flow line coupled to the outer channel claim 1 , the first flow line separate from the second flow line such that fluid flowing into the outer channel does not mix with fluid flowing into the inner channel.7. The ...

Pump Drain Arrangements For Packer Systems And Methods For Sampling Underground Formations Using Same

An apparatus, system and method of sampling a reservoir fluid is disclosed. An inflatable packer is deployed into a wellbore having one or more fluid ports for receiving the reservoir fluid. The fluid ports are positionable at different longitudinal and/or radial positions. One or more pumps are connected to the fluid ports and are within the packer. A fluid exit may optionally be provided in the packer to expel the reservoir fluid received from one of the fluid ports back into the wellbore.

Formation tester tool

A formation tester tool assembly includes a seal member mounted on rigid stabilizer that contacts a borehole wall separately from the seal member, so that seal exposure to a stabilization load that presses the tool against the borehole wall is limited or reduced by contact engagement of the stabilizer with the borehole wall. The stabilizer is provided by a hydraulically actuated probe piston reciprocally movable relative to a tool body on which it is mounted. The seal member is in some embodiments movable relative to the probe piston, for example being configured for hydraulic actuation to sealingly engage the borehole wall while the tool body is stabilized by action of the probe piston.

Embeddable Downhole Probe

A downhole probe assembly is employed in a wellbore to mitigate the effects of hoop stress on the operation of the probe assembly. A shaped head is driven radially into the geologic formation surrounding the wellbore. A sensor and/or fluid ports may thereby be delivered to a radial depth in the geologic formation beyond a hoop stress regime associated with the wellbore. In this manner, analysis and fluid communication with the geologic formation may not be hindered by the hoop stress regime surrounding the wellbore. The probe assembly may be employed in microfracture tests in which fluid is injected into geologic formation through mechanical fractures created by the shaped heads extending through the hoop stress regime. The fluid injected through the hoop stress regime may more readily interact with the geologic formation, and subsequent analysis of the injected fluids may yield more relevant information about the geologic formation. 1. A downhole tool comprising:a tool body defining a longitudinal axis;a radial extension mechanism mounted on the tool body at a first location on the tool body and movable between a radially retracted configuration and a radially extended configuration with respect to the tool body;a shaped head having a proximal end attached to the radial extension mechanism and a distal end at which a vertex is formed; anda straddle packer including a mandrel coupled to the tool body, first and second packer elements axially spaced from one another along the mandrel and a fluid port defined in the mandrel between the first and second packer elements.2. The downhole tool according to claim 1 , further comprising a proppant chamber and a pump operable to deliver fluid from the proppant chamber to the fluid port defined in the mandrel.3. The downhole tool according to claim 2 , further comprising a port defined on the shaped head claim 2 , the port in fluid communication with the proppant chamber.4. The downhole tool according to claim 1 , wherein the ...

Logging device for measuring pressure into an underground formation and associated method

The invention relates to a logging device for measuring pressure into an underground formation, comprising at least one formation pressure sensor which comprises a tool body part and a probe mounted on the tool body part, said probe comprising a fluid withdrawal line. The tool body part comprises a flow line connected to the fluid withdrawal line, at least one test chamber connected to the flow line and an at least one respective closing system, and at least one pressure sensor connected to the flow line. The probe further comprises a rupture chamber and a pressure sensor connected to the fluid withdrawal line and, a first isolating valve on the fluid withdrawal line downstream of the rupture chamber and upstream to the flow line adapted to isolate the rupture chamber from the flow line when the rupture chamber is actuated.

Downhole Fluid Analysis Methods For Determining Viscosity

The present disclosure relates to methods and apparatus for determining a viscosity-pressure profile of downhole fluid by measuring the viscosity at several different pressures during a sampling operation. According to certain embodiments, the viscosity may be measured at different times during a sampling operation and used to generate the viscosity-pressure profile. For example, the viscosity may be measured at the beginning of pumping, during filling of a sample chamber, during a pressure-build up period, and while retracting the probe. The measured viscosities may then be employed to determine a profile that represents the change in viscosity that occurs with pressure.

Thermal Management via Flowline Heat Dissipation

An apparatus that includes a housing, a flowline extending within the housing, and a member retained within the housing and substantially comprising thermally conductive material. The flowline is retained in a substantially cylindrical surface of the member. A heat-generating electrical component is mounted to the member. 1. An apparatus , comprising: a housing;', 'a flowline extending within the housing;', 'a member substantially comprising thermally conductive material, wherein the flowline is retained in a substantially cylindrical surface of the member; and', 'a chassis comprising, 'a heat-generating electrical component mounted to the member., 'a downhole tool for conveyance within a wellbore extending into a subterranean formation, wherein the downhole tool comprises2. The apparatus of wherein fluid flow through the flowline dissipates heat transferred from the heat-generating electrical component to the fluid flow through the member and the flowline.3. The apparatus of wherein the substantially cylindrical surface of the member longitudinally extends substantially through a major dimension of the member.4. The apparatus of wherein the flowline is retained in substantially surface contact with the substantially cylindrical surface of the member.5. The apparatus of wherein the thermally conductive material has a thermal conductivity of at least 100 Watts/meter/° Kelvin.6. The apparatus of wherein:the member is a first member;the chassis further comprises a second member substantially comprising thermally conductive material and coupled with a longitudinal surface of the first member;the substantially cylindrical surface is a first substantially cylindrical surface;the second member comprises a second substantially cylindrical surface; andthe flowline is retained by and between the first and second substantially cylindrical surfaces.7. The apparatus of wherein the second substantially cylindrical surface longitudinally extends substantially through a major ...

Systems and Methods for Controlling Flow Rate in a Focused Downhole Acquisition Tool

A method includes operating a downhole acquisition tool including a guard probe and a sample probe in a wellbore that contains a fluid that includes a native reservoir fluid and a contaminant. The method also includes receiving a first portion of fluid into the guard probe and a second portion of fluid into the sample probe, estimating a contamination level of the first or second portions based on a fluid property of the respective first and second portions, determining an initial guard flow rate of the first portion, determining an initial sample flow rate of the second portion, using a processor to adjust a guard flow rate of the second portion over pump time after the contamination level of the first portion is at or below a contamination level threshold, and adjust a sample flow rate of the first portion based on the adjusted guard flow rate and total flowrate. 1. A method comprising:operating a downhole acquisition tool comprising a guard probe and a sample probe in a wellbore in a geological formation, wherein the wellbore or the geological formation, or both contains a fluid that comprises a native reservoir fluid of the geological formation and a contaminant;receiving a first portion of the fluid into the guard probe and a second portion of the fluid into the sample probe;estimating a contamination level of the first portion of the fluid, the second portion of the fluid, or a combination thereof based on a fluid property of the respective first and second portions of the fluid as measured by the downhole acquisition tool;determining an initial guard flow rate of the first portion of fluid through the guard probe;determining an initial sample flow rate of the second portion of fluid through the sample probe;using a processor to:adjust a guard flow rate of the second portion of the fluid through the guard probe over pump time after the contamination level of the first portion of the fluid is at or below a contamination level threshold, based on the initial ...

PRESSURE MEASUREMENT MITIGATION

A method includes positioning a formation tester tool into a borehole formed within a formation and radially expanding a first and second radially extendable packers of the formation tester tool out from the formation tester tool to the formation to form a sealed volume between the first radially extendable packer and the second radially extendable packer. The method includes radially extending a pad of the formation tester tool that is positioned between the first radially extendable packer and the second radially extendable packer to form a sealed connection volume between the formation and a pressure sensor within the pad. The method includes acquiring a first pressure measurement, using the pressure sensor, from fluids in the sealed connection volume and extracting fluid from the sealed volume to reduce pressure around the pad. The method includes acquiring a second pressure measurement, using the pressure sensor, from fluids in the sealed connection volume. 1. An apparatus comprising: a pressure sensor;', 'a pad that is radially extendable with respect to an axis of the formation tester tool, and wherein the pressure sensor is inside the pad;', 'a first radially extendable packer that is axially above the pad with respect to the axis of the formation tester tool; and', 'a second radially extendable packer that is axially below the pad with respect to the axis of the formation tester tool; and, 'a formation tester tool to be positioned in a borehole within a formation, wherein the formation tester tool comprises,'} cause the first radially extendable packer and the second radially extendable packer to expand from the formation tester tool outward to the formation to form a sealed volume that is isolated from other regions of the borehole;', 'form a sealed connection volume between the formation and the pressure sensor;', 'acquire a first pressure measurement, using the pressure sensor, from fluids in the sealed connection volume;', 'extract fluid from the sealed ...

PRESSURE MEASUREMENT MITIGATION

An apparatus includes a formation tester tool to be positioned in a borehole within a formation, wherein the formation tester tool comprises a pressure sensor and a pad that is radially extendable with respect to an axis of the formation tester tool, and wherein the pressure sensor is inside the pad. The formation tester tool includes first and second inner radially extendable packers that are axially above and below the pad, respectively, with respect to the axis of the formation tester tool. The apparatus includes a first outer radially extendable packer that is axially above the first inner radially extendable packer with respect to the axis of the formation tester tool and a second outer radially extendable packer that is axially below the second inner radially extendable packer with respect to the axis of the formation tester tool. 1. An apparatus comprising: a pressure sensor;', 'a pad that is radially extendable with respect to an axis of the formation tester tool, and wherein the pressure sensor is inside the pad;', 'a first inner radially extendable packer that is axially above the pad with respect to the axis of the formation tester tool;', 'a second inner radially extendable packer that is axially below the pad with respect to the axis of the formation tester tool;', 'a first outer radially extendable packer that is axially above the first inner radially extendable packer with respect to the axis of the formation tester tool; and', 'a second outer radially extendable packer that is axially below the second inner radially extendable packer with respect to the axis of the formation tester tool; and, 'a formation tester tool to be positioned in a borehole within a formation, wherein the formation tester tool comprises,'} cause the first inner radially extendable packer and the second inner radially extendable packer to expand from the formation tester tool outward to the formation to form an inner sealed volume that is isolated from other regions of the ...

Systems and Methods for an Expandable Packer

The present disclosure relates to a downhole packer assembly that includes an outer skin, an inner packer disposed within the outer skin such that inflation of the inner packer is configured to expand the outer skin, a pair of mechanical fittings engaged with axial ends of the outer skin, and a ring assembly disposed within at least one of the pair of mechanical fittings. The ring assembly includes a shear pin configured to shear upon application of a tensile force to the downhole packer assembly. 1. A downhole packer assembly , comprising:an outer skin;an inner packer disposed within the outer skin such that inflation of the inner packer is configured to expand the outer skin;a pair of mechanical fittings engaged with axial ends of the outer skin; anda ring assembly disposed within at least one of the pair of mechanical fittings, wherein the ring assembly comprises a shear pin configured to shear upon application of a tensile force to the downhole packer assembly.2. The downhole packer assembly of claim 1 , wherein the ring assembly comprises a split ring having a first split ring portion and a second split ring portion.3. The downhole packer assembly of claim 1 , wherein the ring assembly comprises a plurality of shear pins disposed circumferentially about the ring assembly.4. The downhole packer assembly of claim 1 , wherein the shearing of the shear pin is configured to enable unsticking of the downhole packer assembly from a wellbore.5. The downhole packer assembly of claim 1 , wherein the shearing of the shear pin is configured to enable axial movement of at least one of the pair of mechanical fittings from a first axial position to a second axial position.6. The downhole packer assembly of claim 5 , wherein the ring assembly covers a sampling port of the downhole packer assembly in the first axial position claim 5 , and the sampling port and an inflation flowline is exposed to a wellbore in the second axial position.7. The downhole packer assembly of claim 1 ...

Acquiring Formation Fluid Samples Using Micro-Fracturing

A formation-tester tool may be positioned downhole in an openhole wellbore. The formation-tester tool may suspend proppant in fracturing fluid located in a chamber of the formation-tester tool. The formation-tester tool may generate a test fracture in an uncased wall of an area of interest of a subterranean formation adjacent to the openhole wellbore and inject the fracturing fluid and the proppant toward the uncased wall and into the test fracture. The formation-tester tool may retrieve a fluid sample from a reservoir within the area of interest of the subterranean formation by creating a drawdown pressure in the test fracture. 1. A method , comprising:suspending, by a formation-tester tool positioned downhole in an openhole wellbore, proppant in fracturing fluid located in a chamber of the formation-tester tool;generating, by the formation-tester tool, a test fracture in an uncased wall of an area of interest of a subterranean formation adjacent to the openhole wellbore;injecting, by the formation-tester tool, the fracturing fluid and the proppant toward the uncased wall and into the test fracture; andretrieving, by the formation-tester tool, a fluid sample from a reservoir within the area of interest of the subterranean formation by creating a drawdown pressure in the test fracture.2. The method of claim 1 , wherein the formation-tester tool is positioned downhole in the openhole wellbore on a wireline claim 1 ,wherein suspending the proppant in the fracturing fluid located in the chamber of the formation-tester tool includes, prior to generating the test fracture, agitating the fracturing fluid by the chamber of the formation-tester tool moving, for at least one interval, in an uphole direction and in an opposing direction in succession.3. The method of claim 2 , wherein the formation-tester tool moves in the uphole direction at a first rate and moves in the opposing direction at a second rate claim 2 ,wherein the first rate is a different rate than the second ...

Clustering Process for Analyzing Pressure Gradient Data

Clustering analysis is used to partition data into similarity groups based on mathematical relationships between the measured variables. These relationships (or prototypes) are derived from the specific correlation required between the measured variables (data) and an environmental property of interest. The data points are partitioned into the prototype-driven groups (i.e., clusters) based on error minimization. Once the data is grouped, quantitative predictions and sensitivity analysis of the property of interest can be derived based on the computed prototypes. Additionally, the process inherently minimizes prediction errors due to the rigorous error minimization during data clustering while avoiding overfitting via algorithm parameterization. The application used to demonstrate the power of the method is pressure gradient analysis.

SYSTEMS AND METHODS FOR MONITORING CHANGES IN A FORMATION WHILE DYNAMICALLY FLOWING FLUIDS

Methods and systems for measuring neutron sigma of downhole reservoir as a function of time for a predetermined testing volume are disclosed. The methods and systems of the present invention analyze the testing volume while maintaining the formation in the testing volume in an unchanged and undamaged state and while dynamically flowing fluids in and out of the testing volume. The systems and methods of the present invention are especially important in determining petrophysical information about the reservoir as well as the in-situ effect of substances on enhanced oil recovery. 1. A down hole formation evaluation tool positionable in a well bore having a wall and positioned within a subterranean formation , the formation having a plurality of constituents and a testing volume therein , the down hole tool comprising:a housing;a positioning device mounted to the housing for releasably fixing the down hole formation evaluation tool against the wall at a predetermined depth within the well bore;a sealing device positioned on the outside of the housing for sealing engagement with the wall of the well bore and providing a sealed area proximate the testing volume;a fluid communication device hydraulically coupled to the housing and the testing volume, the fluid communication device having at least one orifice positioned within the sealed area and a portion of the testing volume for communicating a fluid to and from the testing volume; a neutron energy emitting device for directing energy into the formation; and', 'at least one sensor responsive to a neutron energy response from the formation and providing an apparent sigma of the testing volume;, 'a formation analysis module attached to the housing for analyzing the testing volume, the formation analysis module comprisinga means for correcting the apparent sigma in relation to the testing volume to obtain an intrinsic sigma for the testing volume; andwherein the intrinsic sigma of the testing volume further comprises a ...

DOWNHOLE APPARATUS AND TECHNIQUE TO MEASURE FLUID RESISTIVITY

A method and apparatus are provided to measure fluid resistivity. The method includes driving a first winding at a first frequency to induce a first current in a fluid present in a flow line and then driving the first winding at a second frequency to induce a second current in the fluid present in the flow line. The method includes measuring the first and second currents and based on these results, determining a resistivity of the fluid. The apparatus includes an apparatus usable with a well that includes a flow line and a first winding to circumscribe the flow line. Also included is a transmitter to induce a number of currents in the flow line and a second winding to provide signals used to derive representations of excitation voltages and current magnitudes. The apparatus may further include an engine to determine a resistivity of the fluid in the flow line. 1. A method comprising:driving a first winding at a first frequency to induce a first current in a fluid present in a flow line;driving the first winding at a second frequency other than the first frequency to induce a second current in the fluid present in the flow line;measuring the first and second currents; andbased at least in part on results of measuring the first and second currents, determining a resistivity of the fluid.2. The method of claim 1 , further comprising determining the resistivity based on at least in part on the first frequency and the second frequency.3. The method of claim 1 , wherein measuring the first and second currents comprises using a second winding that is electromagnetically coupled to the first winding.4. The method of claim 1 , wherein:the flow line comprises a dielectric section; anda current path for the induced currents is routed between boundaries between the fluid and the dielectric section.5. The method of claim 4 , wherein the determining the resistivity comprises using the first and second frequencies to eliminate a capacitance associated with the boundaries.6. The ...

Formation Pressure Testing

A pressure testing module separable from and configured to be coupled with a tool base that is to be coupled along a downhole tool string to be conveyed within a wellbore extending into a subterranean formation. The pressure testing module includes a chamber and a piston assembly slidably disposed within the chamber, thus dividing the chamber into a first chamber portion and a second chamber portion. The piston assembly is operable to move in response to hydraulic fluid being pumped into the first chamber portion and to draw formation fluid of the wellbore into the second chamber portion in response to the movement of the piston assembly.

Interpretation of Pressure Test Data

Apparatus and methods for obtaining initial settings of station-specific parameters descriptive of wellbore/formation properties specific to downhole pressure test stations, and obtaining initial settings of station-shared parameters descriptive of petrophysical properties of petrophysically unique formation zones. A pressure transient model of the zones is obtained by regression utilizing the pressure data of each station and the initial settings of the station-specific and station-shared parameters. The regression analytically determines a model value of at least one of the station-specific parameters and the station-shared parameters.

Systems and Methods for In-Situ Measurements of Mixed Formation Fluids

Systems and methods for obtaining in-situ measurements of mixed formation fluids are provided. A downhole acquisition tool may move to a first station in a wellbore in a geological formation to collect a sample of first formation fluid from the first station. The downhole acquisition tool may move to a second station in the wellbore and a sample of second formation fluid may be collected. A proportion of the first formation fluid and the second formation fluid may be mixed within the downhole acquisition tool in-situ while the downhole acquisition tool is within the wellbore to obtain a formation fluid mixture. The formation fluid mixture may be passed into a fluid testing component of the downhole acquisition tool while the downhole acquisition tool is in the wellbore to measure fluid properties of the formation fluid mixture in-situ. 1. A method comprising:moving a downhole acquisition tool to a first station in a wellbore in a geological formation;collecting a sample of first formation fluid from the first station using the downhole acquisition tool;moving the downhole acquisition tool to a second station in the wellbore;collecting a sample of second formation fluid from the second station using the downhole acquisition tool;mixing a proportion of the first formation fluid and the second formation fluid within the downhole acquisition tool in-situ while the downhole acquisition tool is within the wellbore to obtain a formation fluid mixture; andpassing the formation fluid mixture into a fluid testing component of the downhole acquisition tool while the downhole acquisition tool is in the wellbore to measure fluid properties of the formation fluid mixture in-situ.2. The method of claim 1 , wherein:the first station is at a first depth in the wellbore where the first formation fluid derives substantially from a first fluid zone;the second station is at a second depth in the wellbore where the formation fluid derives substantially from a second fluid zone; andthe ...

FORMATION TESTER TOOL ASSEMBLY AND METHOD

An apparatus includes a formation probe assembly that includes a probe piston configured for reciprocal movement between a retracted position and an extended position. The apparatus also includes a draw down assembly in fluid communication with the formation probe assembly. The draw down assembly includes a draw down piston being actuatable between a first position and a second position in a cylinder to draw fluid into the cylinder through the piston in the formation probe assembly and a position indicator configured to determine a position of the draw down piston in the cylinder. The apparatus includes a controller configured to control at least one of a rate and a volume of the fluid being drawn into the cylinder of the draw down assembly based, at least in part, on the position of the draw down piston determined by the position indicator. 1. An apparatus comprising: 'a probe piston configured for reciprocal movement between a retracted position and an extended position in which an outer end of the probe piston projects beyond an outer surface of the formation probe assembly;', 'a formation probe assembly comprising a draw down piston being actuatable between a first position and a second position in a cylinder to draw fluid into the cylinder through the piston in the formation probe assembly; and', 'a position indicator configured to determine a position of the draw down piston in the cylinder; and}, 'a draw down assembly in fluid communication with the formation probe assembly, the draw down assembly comprisinga controller configured to control at least one of a rate and a volume of the fluid being drawn into the cylinder of the draw down assembly based, at least in part, on the position of the draw down piston determined by the position indicator.2. The apparatus of claim 1 , wherein the formation probe assembly is located within a probe drill collar for location within a borehole in a formation.3. The apparatus of claim 2 , wherein the formation probe assembly ...

DOWNHOLE ROBOTIC ARM

An apparatus for manipulating an object in a borehole in an earthen formation includes a body configured to be conveyed along the borehole and a plurality of linear actuators disposed in the body and operatively connected to the object. The plurality of linear actuators applies a translational and rotational movement to the object. A related method includes applying a translational and rotational movement to the object using the plurality of linear actuators. 1. An apparatus for manipulating an object in a borehole in an earthen formation , comprising:a body configured to be conveyed along the borehole; anda plurality of linear actuators disposed in the body and operatively connected to the object, the plurality of linear actuators applying a translational and rotational movement to the object.2. The apparatus of claim 1 , wherein the plurality of linear actuators includes a first and a second linear actuator claim 1 , the first and the second linear actuator each having a first end operatively connected to the object claim 1 , and a second end operatively connected to the body claim 1 , at least one of the first and second linear actuators operatively connected to the body including a joint allowing relative rotational movement.3. The apparatus of claim 1 , wherein the plurality of linear actuators includes a first and a second actuator claim 1 , the first linear actuator having an end operatively connected to the body claim 1 , the second linear actuator having a first end operatively connected to the first linear actuator and a second end operatively connected to the body.4. The apparatus of claim 1 , further comprising at least one fluid channel through the body claim 1 , the at least one fluid channel conveying a fluid during borehole operation.5. The apparatus of claim 1 , further comprising at least one sensor associated with the plurality of linear actuators or the object claim 1 , the at least one sensor measuring a movement of at least one of the plurality ...

DOWNHOLE TOOL WITH FILTRATION DEVICE

Downhole tool is provided that includes a body, an intake port for receiving fluid from external the body, a pump, a filtration device, and an exit port. The pump is in fluid communication with the intake port for withdrawing fluid through the intake port. The filtration device has a particulate removing filter, and a flow line extending from the intake port to the filtration device. The filtration device is contained within the body and is in fluid communication with the intake port. The exit port is in fluid communication with the filtration device for ejecting the fluid to external the body. 1. A downhole tool comprising:a body;an intake port for receiving fluid from external the body;a pump in fluid communication with the intake port for withdrawing fluid through the intake port;a filtration device having a particulate removing filter, a flow line extending from the intake port to the filtration device, the filtration device being contained within the body and in fluid communication with the intake port; andan exit port in fluid communication with the filtration device for ejecting fluid to external the body.2. The downhole tool of claim 1 , further comprising a probe which comprises the intake port claim 1 , the probe having a sealing pad for engagement with a formation surface.3. The downhole tool of claim 1 , the filtration device comprising:a plurality of filter cartridges, each of the plurality of filter cartridges having different particulate filtration sizes;a fluid flow path extending across the plurality of filter cartridges from a first filter cartridge to a final filter cartridge;wherein the particulate filtration sizes of the plurality of filter cartridges progress from the first filter cartridge having the coarsest particulate filtration size to the final filter cartridge having the finest particulate filtration size.4. The downhole tool of claim 3 , wherein the plurality of filter cartridges are arranged in series.5. The downhole tool of claim 4 , ...

INFLOW TESTING SYSTEMS AND METHODS FOR OIL AND/OR GAS WELLS

Systems and methods for testing one or more closeable or fixed ports in a horizontal section of a well are provided. One of the systems comprises a jointed tubing string deployable by a service rig and a bottomhole assembly attached the jointed tubing string, the bottomhole assembly comprising a jet pump, a pressure sealing device, and an intake. The system may further include one or more of a shifting tool, a casing collar locator, an extension tubing, and an isolation device. The system draws fluid from the ports through the intake and the fluid may be tested as it flows through the buttonhole assembly and/or at surface. The isolation device may have a lower portion that is detachable from and re-attachable to the remaining components of the bottomhole assembly thereabove. 1. A method for testing inflowing fluid from one or more test ports in a well , the one or more test ports being in an open position , the method comprising:connecting a bottomhole assembly to a jointed tubing string, the bottomhole assembly comprising a jet pump, a pressure sealing device, and an intake in fluid communication with the jet pump;running the jointed tubing string and the bottom hole assembly into the well using a service rig until the bottom hole assembly reaches the one or more test ports;if there are one or more closeable ports uphole from the one or more test ports, closing the one or more closeable ports while the bottomhole assembly advances into the well;setting the pressure sealing device, the pressure sealing device being uphole from the one or more test ports;supplying power fluid to the jet pump to draw the inflowing fluid into the intake;combining the inflowing fluid received through the intake with the power fluid to form a return fluid;transporting the return fluid to surface; andone or both of: testing the inflowing fluid as it flows through the bottomhole assembly; and testing the inflowing fluid at surface using surface testing equipment.2. The method of claim 1 , ...

FOCUS PROBE FOR UNCONSOLIDATED FORMATIONS

A fluid sampling probe may include one or more features that increase the likelihood that a seal will be maintained during a sampling operation, even for sampling operations in unconsolidated formations. This may reduce contamination in formation fluid samples that are obtained during sampling operations. The fluid sampling probe may include a reinforcement ring configured to extend into a geological formation beyond an elastomer portion of the fluid sampling probe, which may support the geological formation and prevent a failure of the formation during sampling operations. The fluid sampling probe may also include a stop sleeve to prevent overextension that could otherwise cause the geological formation to collapse. In addition, the fluid sampling probe may include a relatively wider sealing elastomer that may decrease in height monotonically radially from the center of the fluid sampling probe. 1. A probe module system for sampling formation fluid from a geological formation , comprising:a guard probe comprising an elastomer portion and a reinforcement ring, wherein the reinforcement ring is at least partially disposed within an elastomer borehole of the elastomer portion, the reinforcement ring extending beyond the elastomer portion, wherein the elastomer portion is configured to press against the geological formation to form a seal during a sampling operation, and wherein the reinforcement ring is configured to support the geological formation during the sampling operation; anda sampling probe disposed within a borehole of the guard probe, wherein the sampling probe is configured to press against the geological formation, and to perform the sampling operation by collecting formation fluid from the geological formation at an interface between a free end of the sampling probe and the geological formation.2. The system of claim 1 , wherein the reinforcement ring is configured to extend claim 1 , relative to the elastomer portion claim 1 , into the geological ...

FLUID ANALYSIS SYSTEM

A vibrating-tube fluid measurement device includes an electrical isolator formed of glass, wherein the vibrating tube tube is mounted to a base block via the electrical isolator and electrically isolated from the base block via the electrical isolator. 1. A method comprising:positioning a doped glass material in a space between a base block and a hollow tube extending into the base block, the hollow tube and the base block being part of a fluid analysis device configured to measure a property of a fluid when the fluid is disposed in the hollow tube;heating the doped glass material to a temperature at which the doped glass material melts;allowing the doped glass material to cool to form a solid glass isolator that mechanically supports the hollow tube with respect to the base block and electrically isolates the hollow tube from the base block.2. The method of claim 1 , wherein the doped glass material is a powder.3. The method of claim 1 , further comprising placing a jig in the base block to support the hollow tube when the doped glass material is melted.4. The method of claim 1 , wherein the jig is comprised of a glass material having a melting point higher that the temperature at which the doped glass material melts.5. The method of claim 1 , wherein the jig is configured to prevent the melted doped glass from flowing out of the base block. This patent application is a divisional application of U.S. patent application Ser. No. 14/947,565, filed Nov. 20, 2015, which is hereby incorporated herein by reference in its entirety.The oil and gas industry have developed various tools capable of determining formation fluid properties. For example, borehole fluid sampling and testing tools such as Schlumberger's Modular Formation Dynamics Testing (MDT) Tool can provide important information on the type and properties of reservoir fluids in addition to providing measurements of reservoir pressure, permeability, and mobility. These tools may perform measurements of the fluid ...

APPARATUS AND METHODS FOR FLUID TRANSPORTATION VESSELS

Methods and systems for collecting high quality reservoir samples and delivering EOR substances are disclosed. The systems and methods disclosed are especially important for collecting samples of reservoir samples in a manner that most closely resembles production fluids and maintains the samples at or above the bubble point of the fluid. 1. A tool for carrying a testing fluid comprising:a housing having at least two pistons slidably disposed therein and dividing the housing into at least three chambers, each of the at least three chambers having a variable volume, including an intermediate chamber, a first end chamber and a second end chamber, the intermediate chamber defined by the pistons and wherein the pistons are free of valves;a first conduit for pressurizing the intermediate chamber with a gas;a second conduit adapted to transfer the testing fluid into and out of the first end chamber;a third conduit adapted to transfer a buffer fluid into and out of the second end chamber; anda tension member having a length less than an axial length of the housing and wherein the tension member is coupled to the at least two pistons.2. The tool of claim 1 , wherein the transfer of the buffer fluid into the second end chamber reduces the volume of the intermediate chamber.3. The tool of claim 1 , wherein the transfer of the buffer fluid out of the second end chamber causes the transfer of the testing fluid into the first end chamber.4. The tool of claim 1 , wherein the transfer of the buffer fluid into the second end chamber causes the transfer of the testing fluid out of the first end chamber.5. (canceled)6. The tool of claim 1 , wherein the tension member comprises a limit bar and the at least two pistons are slidably positioned on the limit bar claim 1 , the limit bar further comprising a shoulder positioned on each end thereof to limit an axial travel of the at least two pistons.7. The tool of claim 6 , wherein the first conduit is disposed within the limit bar.8. The ...

Sample Capture Prioritization

A method for determining formation fluid sample quality includes analyzing sample capture data to identify distinguishing features indicative of whether a successful sample capture has occurred within a downhole tool. The method further includes prioritizing, based on the analysis, the sample capture data for transmission to a surface system.

Sampling Chamber with Hydrogen Sulfide-Reactive Scavenger

Systems, methods and devices for analyzing a sample of fluid extracted from a hydrocarbon-producing geological formation to detect a quantitative amount of hydrogen sulfide or disclosed. The systems methods and devices involve including a scavenger within a sample compartment to react with the hydrogen sulfide therein. The concentration of hydrogen sulfide in the sample may be derived as a function of the amount of scavenger remaining in the sample after reaction with hydrogen sulfide, an amount of byproduct of a reaction between the scavenger and the hydrogen sulfide, or an amount of hydrogen sulfide as measured following a secondary reaction that releases the hydrogen sulfide from the scavenger. 1. A downhole sample chamber for sampling fluid from a formation , the chamber comprising:a fluid inlet;a fluid outlet;a compartment between the fluid inlet to fluid outlet; anda scavenger volume within the compartment, wherein the scavenger volume is reactive with H2S.2. The downhole sample chamber of claim 1 , wherein the compartment comprises a sample fluid containing H2S claim 1 , and wherein the scavenger volume comprises an amount of scavenger composition that is selected to react with a maximum estimated amount of H2S included within the sample fluid.3. The downhole sample chamber of claim 1 , wherein the scavenger volume comprises a spherical volume.4. The downhole sample chamber of claim 3 , wherein a change in size of the spherical volume is indicative of an amount of H2S in the sample fluid.5. The downhole sample chamber of claim 1 , wherein the scavenger volume is reactive with H2S in a non-regenerative reaction.6. The downhole sample chamber of claim 1 , wherein the scavenger volume is reactive with H2S in a regenerative reaction.7. The downhole sample chamber of claim 1 , wherein the scavenger volume comprises a composition selected from the group consisting of iron claim 1 , zinc claim 1 , copper claim 1 , silver claim 1 , ferrous gluconate claim 1 , zinc ...

Downhole acid injection to stimulate formation production

A downhole tool for performing an acid stimulation operation includes a chamber and at least one acid resistant container to store a stimulation fluid comprising a stimulation acid. The at least one acid resistant container can be placed in the chamber prior to conveying the downhole tool in a borehole. The downhole tool can include a fluid injector fluidly coupled to an output of the chamber. After the downhole tool is positioned at a location in the borehole where the stimulation fluid is to be injected into a subsurface formation surrounding the borehole, the at least one acid-container can be opened such that the stimulation fluid can flow from the output of the chamber to the fluid injector. The fluid injector can inject the stimulation fluid into the subsurface formation.

Contamination Prediction of Downhole Pumpout and Sampling

A method may comprise positioning a downhole fluid sampling tool into a wellbore, performing a pressure test operation within the wellbore, performing a pumpout operation within the wellbore, identifying when a clean fluid sample may be taken by the downhole fluid sampling tool from at least the pressure test operation and the pumpout operation, and acquiring the clean fluid sample from the wellbore. A system may comprise a downhole fluid sampling tool and an information handling machine. The downhole fluid sampling tool may further comprise one or more probes attached to the downhole fluid sampling tool, one or more stabilizers attached to the downhole fluid sampling tool, and a sensor placed in the downhole fluid sampling tool configured to measure drilling fluid filtrate. 1. A method comprising:positioning a downhole fluid sampling tool into a wellbore;performing at least one pressure test operation within the wellbore;performing at least one pumpout operation within the wellbore;identifying one or more formation parameters at least in part from the at least one pressure test operation or the at least one pumpout operation;building a correlation model that relates a pumpout trend to the one or more formation parameters; andestimating at least one of a clean fluid composition or a reservoir fluid property in a reservoir fluid using the correlation model.2. The method of claim 1 , further comprising generating the pumpout trend from the at least one pumpout operation.3. The method of claim 2 , further comprising optimizing the one or more formation parameters with the pumpout trend.4. The method of claim 2 , further comprising identifying a contamination within the at least one pumpout operation from the pumpout trend.5. The method of claim 1 , further comprising relating the pumpout trend to the one or more formation parameters with a dataset.6. The method of claim 5 , wherein the dataset includes one or more samples from at least one location outside the wellbore ...