Halliburton Energy Services, Inc.

Shell Oil Comapny

Commonwealth Scientific and Industrial Research Organisation

Bairod Technology, Inc.

Fersheed Khodadad Mody

Ali Mese

Arthur H Hale

Kenneth William Pober

James Van Fisk, Jr

Mustafa Hakimuddin

Calum John Drummond

Uday Arun Tare

Mikhail Boris Geilikman

Wolfgang Friedrich Johann Deeg

George Georgaklis

Darrell Wells

Di Jiao

Chee P Tan

Methods and systems for establishing a double barrier around at least a portion of a subsurface treatment area in a hydrocarbon containing formation are disclosed. First barrier wells may be used to form a first barrier around a portion of the subsurface treatment area. Second barrier wells may be used to form a second barrier around the first barrier. A space may exist between the first barrier and the second barrier. The first barrier and second barrier may be inhibited from forming a single combined barrier by the injection, and in some cases circulation, of fluids such as saline water.

Barrier methods for use in subsurface hydrocarbon formations

A method is disclosed that affords improved stability to wellbores during drilling in argillaceous formations with water-based drilling fluids. The method comprises adding to the drilling fluid a compound of the invention having the capacity in water to generate a highly efficient membrane on argillaceous materials. The compound is soluble in the drilling fluid at least at the pH at which the compound is added to the drilling fluid or exists in the drilling fluid, but is insoluble in the water in the pores of the argillaceous formations, or at least at the pH of the water in such pores.

Compounds and method for generating a highly efficient membrane in water-based drilling fluids

A real-time method is disclosed for maintaining subterranean formation stability through monitoring the interaction between the formation and fluids introduced into (or produced from) a wellbore penetrating the formation. The method employs real-time wellbore (in)stability logging methodology. The method is exemplified by a Pore Pressure Transmission (PPT) test. In such test, test fluids are exposed to Pierre II shales (20% w/w NaCl solution and sodium silicate fluid with 20% w/w NaCl, for example) in a PPT apparatus. Membrane efficiency of the two fluids when exposed to the outcrop shale is calculated, and based on the simultaneous acquisition of acoustic data, estimation of a dynamic rock property is made. Calibrating representative shale (or other formation) core response to drilling fluids (or well service fluids, enhanced recovery fluids, or production fluids) under realistic in-situ conditions aids in accurately modeling for time-dependent formation (in)stability in the field for the entire life of the wellbore, from drilling, completion and through production.

Real-time method for maintaining formation stability and monitoring fluid-formation interaction

A real-time method is disclosed for maintaining subterranean formation stability through monitoring the interaction between the formation and fluids introduced into (or produced from ) a wellbore penetrating the formation. The method employs real-time wellbore (in)stability logging methodology. The method is exemplified by a Pore Pressure Transmission (PPT) test. In such test, test fluids are exposed to Pierre II shales (20% w/w NaCl solution and sodium silicate fluid with 20% w/w NaCl, for example) in a PPT apparatus. Membrane efficiency of the two fluids when exposed to the outcrop shale is calculated, and based on the simultaneous acquisition of acoustic data, estimation of a dynamic rock property is made. Calibrating representative shale (or other formation) core response to drilling fluids (or well service fluids, enhanced recovery fluids, or production fluids) under realistic in-situ conditions aids in accurately modeling for time-dependent formation (in)stability in the field for the entire life of the wellbore, from drilling, completion and through production.

A water-based drilling fluid for use in shale formations having a given average pore size has solutes dissolved therein sized so as to allow the pores of the shale formations to at least partially restrict the solutes. For purposes of enhancing the restriction of the solutes by the shale pores, the dissolved solutes may have different radii. Additional solutes, preferably lower molecular weight salts, are dissolved in the drilling fluid to lower the activity of the water in the water-based drilling fluid. The same combination of additives, a first additive of dissolved molecular solutes sized to at least partially block a shale pore space and a second additive of dissolved molecular solutes selected to lower the water activity, are combined in a water-based carrier fluid and used in earth boreholes surrounded by shale formations as either a spotting fluid, or as a lubricant, or as a shale formation strengthener or as a completion fluid.

Water-based drilling fluid for use in shale formations

A method for drilling utilizing a composition comprising water, a water-soluble polyalcohol, a water-insoluble alcohol, and drill solids. Also, a composition ideally suited for drilling is provided comprising water, a mixture of water-soluble and insoluble alcohols and drill solids.

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Houston, TX, United States of America

Fersheed Khodadad Mody