Exxon Production Research Company

Clay Gruesbeck

Thomas W Muecke

William M Salathiel

Claude E Cooke, Jr

John W Graham

Charles O Stokley

Walter L Penberthy, Jr

A method and apparatus for sampling the composition of fluid flowing through a conduit which includes a sampling conduit having an inlet disposed within said conduit and transverse to the axis of fluid flow in said conduit and an outlet connected to said conduit downstream of said inlet, and means for measuring the composition of fluid flowing through the sampling conduit. The sampling conduit is sized in relation to the conduit to cause isokinetic withdrawal of fluid from said conduit into said sampling conduit.

Apparatus and method for sampling flowing fluids and slurries

A method is described for using ball sealers as a diverting agent when treating a subterranean formation penetrated by a well provided with casing having perforations at a plurality of levels. Ball sealers sized to plug a perforation, a first fluid having a density greater than the ball sealers and a second fluid less dense than the ball sealers are introduced into the casing concurrently or in any order. The amount of the first fluid introduced should be sufficient to fill the lower portion of the casing to a level between the lower perforations to be plugged and the upper perforations to be left open to fluid flow. Once the ball sealers are disposed below the upper perforations, treating fluid is injected into the casing to cause a flow of the second fluid through the lower perforations to carry the ball sealers down the casing to plug the lower perforations and to cause fluid flow through the upper perforation which the ball sealers did not plug.

Selective wellbore isolation using buoyant ball sealers

The annular passage defined by the interior of a perforated liner and the exterior of a stinger pipe extending through the liner is substantially restricted so that the resistance to flow in the annular passage is increased sufficiently to maintain high fluid flow velocity outside the liner during gravel packing. The increased flow velocity prevents the premature settling of gravel and stabilizes the formation of gravel dunes in the wellbore annulus, thereby significantly increasing gravel packing efficiency in inclined wells. The proper flow restriction can be obtained using a wide diameter stinger pipe.

Method and apparatus for gravel packing wells

A well completion and workover method wherein a subterranean formation is contacted with a high density, nondamaging treating fluid which comprises a saturated, aqueous solution having finely divided particles of a water soluble salt suspended therein. The saturated aqueous saline solution should have a density of at least about 1.2 g/cc and the suspended salt particles should be present in sufficient quantities to substantially increase the overall density of the treating solution. The preferred fluid comprises a suspension of pulverized sodium chloride in a saturated calcium chloride solution. Dispersants and viscosifiers can be added in minor amounts to help maintain the salt particles in suspension.

Well completion and workover method

A perforated liner is sealed at longitudinally spaced intervals with a removable sealant. The partially sealed liner maintains sufficiently high fluid flow velocity outside the liner during gravel packing so as to prevent the formation of gravel dunes. After packing is completed, the sealant is removed permitting the passage of fluids through the liner.

A hydraulic fracturing method wherein a viscous oil-in-water emulsion is injected into a formation under sufficient pressure to fracture the formation. The emulsion contains from about 70 to about 90 volume percent of an internal liquid hydrocarbon phase, from about 10 to about 30 volume percent of an external aqueous phase and sufficient amounts of a nonionic surfactant to stabilize and viscosify the emulsion. The preferred hydrocarbon phase concentration is between about 75 and 85 volume percent. The nonionic surfactant also gives the emulsion a breaking temperature which is not greater than the temperature of the formation. Preferably, an electrolyte is used to adjust the temperature at which the emulsion will break. After fracturing is completed the emulsion is then left in the wellbore for a sufficient time to permit the temperature of the emulsion to reach its breaking temperature. Upon breaking, the emulsion reverts to a low viscosity fluid which is readily removable from the formation.

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Houston, TX, United States of America

Clay Gruesbeck