Abstract: A method is disclosed for semi-automatic or automatic control of a system for changing drilling tools for a drilling rig that includes a drill tower supporting a drill string with a drill pipe at a lowermost end, and a drilling tool changer assembly having a rotatable carousel assembly with a plurality of bit adaptors for holding drilling tools. The method includes removing a first drilling tool attached to the drill pipe and attaching a second drilling tool held in the rotatable carousel assembly to the drill pipe. The method may selectively be performed semi-automatically or automatically via a control system operatively coupled to the drilling rig.

Abstract: A system has a riser and a termination body, the termination body being arranged to connect at least one first conduit arranged along the riser and at least one second conduit extending from the riser to a drilling rig, where the termination body has a first clamp body and a second clamp body arranged for mutual joining and radial enclosure of a portion of the riser, and at least one receptacle block for connecting the at least first conduit, where the portion of the riser is unsplit. A method for connecting the termination body to the riser is also disclosed.

Abstract: A riser assembly includes a riser with a first and second riser joint, an auxiliary line, and a first and second flange. The auxiliary line has an auxiliary line joint which connects a first and second auxiliary line section. The auxiliary line joint has a first joint assembly connected to the first auxiliary line section, and a second joint assembly connected to the second auxiliary line section. The first and second joint assembly each have a bearing surface. A bearing surface of the first flange engages the bearing surface of the first joint assembly. A bearing surface of the second flange engages the bearing surface of the second joint assembly. The bearing surface of the first flange or of the first joint assembly also has a rocker formation which contacts the bearing surfaces of the first flange and of the first joint assembly while permitting a relative angular movement therebetween.

Abstract: The disclosure provides a downhole completion device for use in a wellbore and a subterranean production well. In one embodiment, the downhole completion device includes: (1) a hydraulic line controlled device, the hydraulic line controlled device having a control line port and one or more fluid leakage paths, and (2) a density barrier having first and second ends, wherein the first end is coupled to the control line port and the second end is configured to couple to a control line extending from a surface installation, the density barrier having an axial loop relative to the hydraulic line controlled device and positioned below the fluid leakage path, thereby preventing migration of leakage fluid from the one or more fluid leakage paths to the surface installation.

Abstract: A riser sensor unit is used to sense engagement of a subsea riser tool with a riser coupling. The riser sensor unit includes a power supply configured to convert alternating current to direct current, an intrinsic safety barrier connected to the power supply, and a first sensor powered by the intrinsic safety barrier. The first sensor is attached to a sub of the subsea riser tool and is configured to generate a first signal upon detecting contact of a bottom surface of the sub with the riser coupling. The intrinsic safety barrier is configured to receive the first signal from the first sensor and transmit the first signal to a control system located remotely from the intrinsic safety barrier.

Abstract: A downhole nipple assembly includes a main body with a central bore configured to receive a hydraulically operated wireline-retrievable subsurface safety valve (WLSSSV and a pressure chamber open to the central bore via a sidewall port. The pressure chamber is configured to receive a volume of wellbore fluid from the central bore via the sidewall port as the nipple assembly is disposed within the wellbore prior to receipt of the WLSSSV in the central bore, and such that the sidewall port is in fluid communication with a pressure inlet port of the WLSSSV is locked in the central bore. The nipple assembly also includes an electrically operated piston assembly comprising a motor operable to drive a piston in response to an electric signal, thereby decreasing the volume of the pressure chamber and generating an increase in hydraulic pressure of the wellbore fluid at the pressure inlet port of the WLSSSV.

Abstract: An oil production system and method. The system includes a system for heating unrecovered oil. The system includes a chemical injection well having at least one subterranean outlet. The system also includes an oil production well with at least one subterranean inlet. The subterranean outlet is lower in elevation than the at least one inlet. The chemical injection well is coupled to an injected reactant source, and wherein said injected reactant source reacts with a second reactant in an exothermic reaction.

Abstract: A pivoting guide arch is provided. The guide arch includes a guide having a curved portion to receive a coiled tube and to guide the tube as the tube traverses between a reel and a wellbore. The guide arch also includes a support structure extending from a first end of the guide that is configured to mechanically support the guide, and a swivel mount that is rotatably coupled to a wellhead to enable the guide and support structure to pivot about an axis of the wellhead.

Abstract: A friction reduction system disposable in a wellbore includes a first valve member including an inner surface which includes a valve seat; and a second valve member rotatable concentrically about a central axis of the first valve member and including a radial port coverable by the valve seat of the outer valve member, wherein the friction reduction system includes an open configuration that provides a maximum flow area through a valve of the friction reduction system including the second valve member and the first valve member, wherein the friction reduction system includes a closed configuration that provides a minimum flow area through the valve which is less than the maximum flow area, and wherein the friction reduction system is configured to generate a pressure pulse in a fluid flowing through the friction reduction system in response to the friction reduction system transitioning from the open configuration to the closed configuration.

Abstract: The present disclosure relates to gravity feeding coiled tubing (CT) into a live well. A method may include gravity feeding the CT into the live well having a wellhead, a line in fluid communication with the wellhead, a CT stripper and pressure control equipment (PCE) disposed above the wellhead, and a safety valve disposed below the wellhead, the method comprising: injecting a fluid through the line and into the wellbore to displace reservoir fluid positioned above the safety valve such that at least a portion of the reservoir fluid is forced below the safety valve; closing the safety valve; releasing pressure from between the PCE and the safety valve via the line; gravity feeding the CT into the wellbore; isolating pressure between the PCE and the safety valve; manipulating pressures on both sides of the safety valve; opening the safety valve; and gravity feeding the CT past the safety valve.

Abstract: System and method for the optimized production of hydrocarbons from shale oil reservoirs via cyclic injection to achieve an improved and optimal recovery of oil. The method can determine and optimize the composition of injected fluids to be injected, the rate, pressure and duration of injection, the production rate and pressure of produced fluids; can determine and utilize the optimum number of injection and production cycles; can determine the amount of soaking time (if any); and can determine the equipment design and operating characteristics to provide for the optimized injection of injection fluids, and the separation of produced fluids for both reinjection and delivery to sales or storage.

Abstract: A method of plugging a section of a wellbore wall includes sending a plug injection tool to a downhole location proximate the section of the wellbore wall, setting a first seal below the section of the wellbore wall using the plug injection tool, and setting a second seal above the section of the wellbore wall using the plug injection tool. A plugging material is pumped between the first and second seals and held there until it solidifies.

Abstract: An autonomous flow control device includes a valve assembly having a fluid inlet and a fluid outlet. A valve element is disposed between the fluid inlet and the fluid outlet. The valve element has a viscosity dominant flow path configured to provide a first flow resistance and an inertia dominant flow path configured to provide a second flow resistance that is greater than the first flow resistance such that when the viscosity of the fluid flowing therethrough is greater than a first predetermined level, the fluid follows the viscosity dominant flow path with the first flow resistance and when the viscosity of the fluid flowing therethrough is less than a second predetermined level, the fluid follows the inertia dominant flow path with the second flow resistance, thereby regulating the production rate of the fluid responsive to changes in the viscosity of the fluid.

Abstract: A unitized wellhead assembly includes a lower wellhead housing and an upper wellhead housing interconnected by internal and external threads and pressure sealed via a housing seal that creates a unitized body. The unitized wellhead assembly accepts casing and tubing hanger assemblies containing a plurality of individual retainer segments that engage mating grooves in the unitized body and also retains the casing and tubing hangers in place while containing the wellbore pressure. By eliminating the porting for external actuation devices that pass through the wall section of a wellhead housing, the potential for accidental release of wellbore gasses or fluids to the atmosphere and creation of a potentially hazardous or deadly situation is eliminated. Additionally, the configuration of the segmented retainers reduces high stresses when the retainers are forced outward and eliminates the potential to yield a retainer ring beyond the point of being able to return to its original shape.

Abstract: A system for liquid surge protection of a subsea riser having a horizontal portion on the seabed and a sag bend portion includes: a flexible tubing having a top end and a bottom end; a plurality of autonomous valves configured to permit liquid to pass through into the flexible tubing, wherein the autonomous valves are arranged between the top end and the bottom end of the tubing; and an inlet device coupled to the bottom end of the flexible tubing, wherein said inlet device is biased against a bottom wall the riser.

Abstract: A method of lowering a discrete load from a pipelay vessel comprises holding a rigid rod on an upright launch axis where the rod extends through a hold-back system; coupling a lower end of the rod to the load; connecting a wire to the load either directly or indirectly via the rod; operating the hold-back system to advance the rod downwardly, hence submerging the load, while the weight of the load is suspended from the hold-back system via the rod; when the load is under mater and beneath the splash zone, transferring the weight of the load directly or indirectly from the hold-back system to the wire; and continuing to lower the load in the water, suspended directly or indirectly from the wire. The method may be reversed to recover a load from a subsea location, such as when lifting a wellhead or blowout preventer from the seabed.

Abstract: A method creates a fluid communication path between a first production well and a second production well. At least one hydraulic fracture intersects the first production well and is separated from the second production well by a wall thereof. The method includes identifying, from the second production well, a location of the hydraulic fracture of the first production well, and perforating the wall of the second production well at the identified location. The perforating creates the fluid communication path between the production wells. Injection of fracking fluid and proppant at the first production well allows for additional fluids to be extracted from the second production well, thus generating a flow between the two production wells through the hydraulic fracture.

Abstract: Disclosed is a fracturing method with synergistic effects of energy enhancement, oil displacement, huff and puff, imbibition, and displacement, comprising the following steps: selecting a well that has never been fracted as a fracturing well; dividing the target layer into several fracturing intervals; performing perforating operations on each fracturing interval of the fracturing well; injecting pore cleaning fluid into the fracturing well to perform pore cleaning and acidizing pretreatment on each cluster perforation; designing fracturing construction parameters; alternately injecting slick water fracturing fluid and oil-displacement slick water fracturing fluid into each of the fracturing layers. The beneficial effects of this disclosure are: the construction method of slick water fracturing fluid with high pump rate and large displacement can form a more complex fracture network structure, tap the production potential of the target reservoir, and further improve the stimulation effect of the reservoir.

Abstract: Examples described herein provide for modeling acid flow for acid stimulation of a formation. An example method includes receiving data about the acid stimulation. The method further includes modeling, by applying the data about the acid stimulation to a model, a wormhole velocity of an acid injected into the formation during the acid stimulation, wherein the wormhole velocity is a function of a Darcy velocity of the acid. The method further includes determining whether the wormhole velocity satisfies a wormhole velocity threshold. The method further includes, responsive to determining that the wormhole velocity fails to satisfy the wormhole velocity threshold, modifying a stimulation parameter to adjust the wormhole velocity of the acid. The method further includes performing the acid stimulation based at least in part on the modified stimulation parameter.

Abstract: A float apparatus includes a buoyant device that has an outer surface with a first end portion, a second end portion and an elongated portion. The elongated portion extends from the first end portion to the second end portion. The buoyant device is shaped and configured to attach to a conduit. The elongated portion of the outer surface has a concaved section that extends from the first end portion to the second end, portion. The concaved section has a shape that complements an cuter radius of the conduit with the buoyant device attached to the conduit.