Abstract: A method for automatically measuring a property of a fluid associated with a drilling application, including obtaining a sample of the fluid, wherein the sample of the fluid is obtained by directing the fluid through an electrode probe assembly comprising an electrode probe and depositing the fluid in a probe gap between electrodes of the electrode probe, ramping up a voltage applied to the electrodes of the electrode probe until a threshold current is obtained, recording the breakdown voltage at the threshold current value, and using the breakdown voltage to compute the property of the sample of the fluid.

Abstract: A method for recovering gas from a subterranean formation having a hydrate deposit located therein and a gas reservoir located under the hydrate deposit that includes injecting a hydrate-forming fluid into an upper region of the gas reservoir neighboring the hydrate deposit; and producing gaseous hydrocarbons from a lower region of the gas reservoir is disclosed.

Abstract: A method for planning a wellbore, the method including defining drilling data for drilling a segment of a planned wellbore and identifying a risk zone in the segment. Additionally, the method including determining an expected fluid loss for the risk zone and selecting a solution to reduce fluid loss in the risk zone. Furthermore, a method for treating drilling fluid loss at a drilling location, the method including calculating a drilling fluid loss rate at the drilling location, classifying the drilling fluid loss based on the drilling fluid loss rate, and selecting a solution based at least in part on the classifying.

Abstract: A method for recovering gas from a subterranean formation having a hydrate deposit located therein and a gas reservoir located under the hydrate deposit that includes injecting a hydrate-forming fluid into an upper region of the gas reservoir neighboring the hydrate deposit; and producing gaseous hydrocarbons from a lower region of the gas reservoir is disclosed.

Abstract: A method of determining a particle size distribution in a wellbore fluid including collecting a volume of mud from a vibratory separator, sampling a volume of the collected mud, and testing the volume of collected mud with a test kit to determine the concentration of a sized additive in the mud is disclosed. A system for determining particle size distribution of a fluid, the system including a vibratory separator, a meter configured to receive a separated material from the vibratory separator, a counter configured to count the number of loads collected by the meter, a test kit including a sieve and a measuring tube, and a centrifuged configured to receive the measuring tube is also disclosed.

Abstract: A method for automatically measuring a property of a fluid associated with a drilling application, including obtaining a sample of the fluid, wherein the sample of the fluid is obtained by directing the fluid through an electrode probe assembly comprising an electrode probe and depositing the fluid in a probe gap between electrodes of the electrode probe, ramping up a voltage applied to the electrodes of the electrode probe until a threshold current is obtained, recording the breakdown voltage at the threshold current value, and using the breakdown voltage to compute the property of the sample of the fluid.

Abstract: A process for generating and subsequently breaking a filter cake, including dissolving a non-reactive gas in a wellbore fluid to form an energized fluid; pumping the energized fluid into a formation at a downhole pressure, wherein the pumping is at overbalanced conditions; producing a filter cake; and decreasing the down hole pressure to below a cut point of the dissolved gas in the energized fluid to form a vapor phase, wherein the vapor phase compromises the integrity of the filter cake is disclosed.

Abstract: A method for planning a wellbore, the method including defining drilling data for drilling a segment of a planned wellbore and identifying a risk zone in the segment. Additionally, the method including determining an expected fluid loss for the risk zone and selecting a solution to reduce fluid loss in the risk zone. Furthermore, a method for treating drilling fluid loss at a drilling location, the method including calculating a drilling fluid loss rate at the drilling location, classifying the drilling fluid loss based on the drilling fluid loss rate, and selecting a solution based at least in part on the classifying.

Abstract: Compositions for increasing the thermal and pressure stability of well fluids viscosified using viscoelastic surfactants, the compositions including an effective amount of an oligomeric or polymeric compound that has a thermally stable backbone structure and at least one pendent viscoelastic surfactant functional group. Preferred compositions for increasing the stability of well fluids viscosified using monomeric viscoelastic surfactants include an effective amount of an oligomeric or polymeric compound that has a thermally stable backbone structure and a multiplicity of pendent viscoelastic surfactant functional groups attached to said backbone structure through relatively long hydrocarbon chains, 1 to 18 carbons in length.

Abstract: A process for generating and subsequently breaking a filter cake, including dissolving a non-reactive gas in a wellbore fluid to form an energized fluid; pumping the energized fluid into a formation at a downhole pressure, wherein the pumping is at overbalanced conditions; producing a filter cake; and decreasing the down hole pressure to below a cut point of the dissolved gas in the energized fluid to form a vapor phase, wherein the vapor phase compromises the integrity of the filter cake is disclosed.

Abstract: The present invention generally relates to improved clay-based compositions comprising colloidal or colloidal-like phases (e.g., emulsions, aphrons) and methods of using those compositions. The compositions generally comprise an aqueous continuous phase, one or more palygorskite-sepiolite group clays, one or more surfactants, aphrons and optionally one or more Aphron Stabilizers. The compositions of the present invention are capable of being used in high-pressure applications.

Abstract: Compositions for increasing the thermal and pressure stability of well fluids viscosified using viscoelastic surfactants, the compositions including an effective amount of an oligomeric or polymeric compound that has a thermally stable backbone structure and at least one pendent viscoelastic surfactant functional group. Preferred compositions for increasing the stability of well fluids viscosified using monomeric viscoelastic surfactants include an effective amount of an oligomeric or polymeric compound that has a thermally stable backbone structure and a multiplicity of pendent viscoelastic surfactant functional groups attached to said backbone structure through relatively long hydrocarbon chains, 1 to 18 carbons in length.

Abstract: A process to substantially reduce fluid loss in which an appropriate amount of a non-flowing gel of sufficient strength is emplaced to substantially eliminate or reduce loss of the drilling fluid. The gel composition of the process includes: (1) a non-cellulose containing copolymer having vinyl phosphonate co-monomer units which may be incorporated into the polymer by copolymerization with the other co-monomer(s) comprising the polymer or by grafting upon an already existing polymer or co-polymer, (2) a crosslinking agent active upon the phosphonate groups, (3) a crosslinking initiator comprising a Bronsted Lowry base or Lewis base and (4) an aqueous solvent.

Abstract: The present invention generally relates to improved compositions comprising stabilized colloidal or colloidal-like phases (e.g., emulsions, aphrons) and methods of using those compositions. The compositions generally comprise an aqueous continuous phase, one or more viscosifiers, one or more surfactants, aphrons and one or more Aphron Stabilizers. The compositions of the present invention possess aphrons with significantly increased half-life and enhanced ability to seal permeable formations, and are capable of being used in high pressure applications.

Abstract: The present invention generally relates to improved aerated compositions comprising stabilized colloidal or colloidal-like phases (e.g., emulsions, aphrons) and methods of using those compositions. The compositions generally comprise an oleaginous bulk phase, an aqueous minor phase, one or more surfactants, aphrons and one or more aphrons stabilizers. The compositions of the present invention are stable, having increased half-lives and are capable of being used in high pressure applications.

Abstract: The present invention generally relates to improved compositions comprising stabilized collodial or colloidal-like phases (e.g., emulsions, aphrons) and methods of using those compositions. The compositions generally comprise an aqueous continuous phase, one or more viscosifiers, one or more surfactants, aphrons and one or more Aphron Stabilizers.

Abstract: Compositions for increasing the thermal and pressure stability of well fluids viscosified using viscoelastic surfactants, the compositions including an effective amount of an oligomeric or polymeric compound that has a thermally stable backbone structure and at least one pendent viscoelastic surfactant functional group. Preferred compositions for increasing the stability of well fluids viscosified using monomeric viscoelastic surfactants include an effective amount of an oligomeric or polymeric compound that has a thermally stable backbone structure and a multiplicity of pendent viscoelastic surfactant functional groups attached to said backbone structure through relatively long hydrocarbon chains, 1 to 18 carbons in length.

Abstract: A composition and method for inhibiting the attack of aqueous corrosive fluids on metal by contacting the metal with a composition including an .alpha.,.beta.-unsaturated aldehyde and a surfactant.