A scale inhibitor includes an amount of hydroxyethylidene diphosphonic acid (HEDP), and an amount of hydroxyapatite. The amounts are combined to form a composition that is long lasting, high activity and completely dissolvable. The composition has a preferred particle size of less than 200 nm. Dicalcium phosphate, tricalcium phosphate, bone and/or bone ash may be used in place of hydroxyapatite.

An in-line treatment cartridge and methods of using same are disclosed. The in-line treatment cartridge can include a cylindrical body configured to allow fluid to flow therethrough and a plurality of particulates contained within the body. At least one particulate of the plurality of particulates can include a chemical treatment agent. The at least one chemical treatment agent can separate from the at least one particulate upon contact with a fluid.

Disclosed are a high-temperature-resistant tertiary amine-grafted silica nano-plugging agent and water-based drilling fluids, relating to oil-gas field drilling. The nano-plugging agent is prepared from a hydrazine compound, a diallyl compound, an enamine compound, silica particle, and an amino-containing silane coupling agent by stepwise reaction. The nano-plugging agent has a grain size of 58-280 nm.

Methods and compositions for servicing a wellbore and, in certain embodiments, to the use of compositions in a wellbore to mitigate lost circulation. In some embodiments, the methods include providing a treatment fluid that includes an aqueous base fluid, a lost circulation material, and a rheology modifier that includes a nanocellulose material; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation including a loss zone; and allowing the treatment fluid to rapidly defluidize in the loss zone.

The invention is directed to hydrophilic and hydrophobic superparamagnetic nanoparticles and their use as contrast agents for NMR including agents that distinguish oil and water in NMR logging of geological formations containing oil or water. Methods of making these SPIONs are also described.

A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore into the subterranean geological formation thereby producing a formation fluid including hydrogen sulfide (H.sub.2S). The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid composition includes 0.25 to 2 wt.% of a primary H.sub.2S scavenger which is potassium permanganate. The drilling fluid composition includes an invert emulsion includes a continuous phase including palm oil and a dispersive phase including water. The potassium permanganate present in the drilling fluid composition reacts with the H.sub.2S present in the formation fluid to produce a dispersion of manganese-containing particles which are at least one selected from the group consisting of manganese sulfide and manganese sulfate.

A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore in the subterranean geological formation thereby producing a formation fluid. The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid includes 0.05 to 1 wt. % of a rhamnolipid surfactant based on a total weight of the drilling fluid. The drilling fluid includes an invert emulsion including a continuous phase and a dispersive phase including water.

A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore into the subterranean geological formation thereby producing a formation fluid including hydrogen sulfide (H.sub.2S). The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid composition includes 0.25 to 2 wt. % of a primary H.sub.2S scavenger which is potassium permanganate. The drilling fluid composition includes an invert emulsion which includes a continuous phase including mineral oil and a dispersive phase including water. The potassium permanganate present in the drilling fluid composition reacts with the H.sub.2S present in the formation fluid to produce a dispersion of manganese-containing particles which are at least one selected from the group consisting of manganese sulfide and manganese sulfate.

A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore in the subterranean geological formation thereby producing a formation fluid. The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid includes 1 to 3 wt. % of a weighting agent which includes hydrophobic metallic zinc nanoparticles including a metallic core and organic ligands present on a surface of the metallic core, based on a total weight of the drilling fluid. The drilling fluid includes an invert emulsion including a continuous phase and a dispersive phase including water.

Aqueous well treatment fluids especially suited for use in far field diversion in low viscosity carrier fluids comprise water, a friction reducer, and a diverter. The diverter comprises dissolvable particulates and proppants. The dissolvable particulates have a specific gravity of from about 0.9 to about 1.6 and a particle size of about 50 mesh or less. The proppants have a specific gravity of from about 0.9 to about 1.4 and a particle size of from about 20 to about 100 mesh. The dissolvable particulates have a higher specific gravity and a smaller particle size than the proppant.