Systems and methods for selecting and performing gas deliverability tests are disclosed. In one embodiment, a method of performing a gas deliverability test includes drilling a well, operating the well to produce gas, determining a sustainability of the well, and determining at least one of a shut-in bottom hole pressure and pressure build-up of the well and a geochemical analysis of the well. The method further includes selecting a deliverability test based at least in part on a duration of an operation of the well, a sustainability of the well, and at least one of the shut-in bottom hole pressure, the pressure build-up and the geochemical analysis of liquids of the well. The method also includes applying the deliverability test to the well.

Various embodiments provide methods and systems for providing fluid lighteners for use in downhole wells. The fluid lighteners may include one or more viscosifiers, one or more aphron generators, and a location-specific non-emulsifying surfactant.

An example CO.sub.2 monitoring systems is configured for monitoring levels of CO.sub.2 in a wellbore. A CO.sub.2 monitoring system may include one or more laser monitoring tools. A laser monitoring tool may include an optical element to output a laser beam, a detector to receive the laser beam, a first chamber housing the optical element and detector, and a second chamber including an inlet and an outlet receive and release, respectively, wellbore fluid. The first chamber may be in fluid connection with second chamber via a gas permeable membrane. Gas may permeate from second chamber into first chamber. Gas in the first chamber is subjected to a laser beam. Absorption of light by the gas is measured, and content of gas is determined based at least in part on the amount of light absorption by the gas.

A downhole tool is positioned in a borehole of a geological formation at a given depth. A formation property is determined at the given depth. The positioning and determining is repeated to form data points of a data set indicative of formation properties at various depths in the borehole. One or more outlier data points is removed from the data set based on first gradients to form an updated data set. One or more properties associated with a reservoir compartment are determined based on second respective gradients associated with the updated data set.

A treatment system comprises a treatment bladder associated with a volume of a tubing-casing annulus of a wellhead system to be treated. The treatment bladder contains a treatment fluid and is at an elevated pressure. The treatment bladder is coupled to the tubing-casing annulus utilizing a fluid conduit through a lower fluid junction. The fluid conduit permits two-way fluid communication between the treatment bladder and the tubing-casing annulus. A method for treating the tubing-casing annulus includes coupling the treatment bladder containing the treatment fluid of the treatment system to the tubing-casing annulus of the wellhead system using the fluid conduit, establishing two-way fluid communication between the tubing-casing annulus and the treatment bladder though the fluid conduit, halting fluid communication though the fluid conduit, and decoupling the treatment bladder from the tubing-casing annulus.

A method and system can obtain real time property measurements of a fluid comprising a formation fluid downhole, real time measurements of an amount of an interactive component of the fluid downhole, and real time measurements of an amount of a non-interactive component of the fluid downhole. The method and system further includes determining a total amount of the interactive component in the fluid or a contamination level of the formation fluid at a time of interest based on the real time property measurements of the fluid downhole and the real time measurements of the amounts of the interactive component and non-interactive component downhole. The real time measurements of the amount of the interactive component downhole are real time measurements of the amount of the interactive component in its free form downhole, and the property can be scaled with the contamination level.

Asphaltene onset pressure of a formation fluid is determined by subjecting the fluid to a plurality of tests where depressurization is conducted at a different depressurization rate for each test while optically monitoring the fluid for asphaltene flocculation. The pressures at which asphaltene flocculation are detected in each test are fit to a curve as a function of depressurization rate, and the curve is extrapolated to a pressure (e.g., 0 psi) to provide the asphaltene onset pressure.

An object of the disclosure is to determine the remaining saturation of existing fluids in naturally fractured and/or homogeneous reservoirs, considering an unconventional tracer test, using the double tracer test method with pressure monitoring (PDTcMP®), which also integrates unused technical elements, in order to estimate more accurately the value of the remaining oil saturation (ROS) in naturally fractured reservoirs, unlike conventional methods used most commonly in homogeneous media. The disclosure substantially modifies the conventional tracer test, as it uses innovative technical elements, which reduce the uncertainty and/or ambiguity associated with conventional tracer tests, when they are applied in naturally fractured reservoirs.

A method including, 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.

A method to manipulate a well comprising providing an apparatus (60) in a well (14) below a packer (22) or other annular sealing device, the apparatus comprising a container (68) having a volume of gas which is sealed at the surface and nm into the well, such that the pressure in the container (68) is at a lower pressure than the surrounding well. When the apparatus is below the packer, a wireless control signal, is sent to operate a valve assembly (62) to selectively allow fluid to enter the container whereby at least 50 litres of fluid is drawn into the container. In this way, the apparatus can be used independent of perforating guns, to clear perforations or other areas in the well or may be used for a variety of tests such as an interval test, drawdown test or a connectivity test such as a pulse or interference test.